Emergency salvage of a crumbled oceanic oil well

ABSTRACT

Oceanic petroleum oil wells, though evolving over decades in technology, catastrophic events with mortality and morbidity, and damage to the aquatic and terrestrial ecosystem are still threats to any ventures in this intriguing avenue. 
     The present embodiments of inventions are directed to emergency measures to weather through adversities of some commonly encountered situations. They further include temporary and permanent reparative measures aiming at salvaging the oil well, whose work and economic involvements are far from normal dimensions. The novelty, simplicity, and workability in situations when none such consolations exist, the instant inventions are worthy of a try by all measures. 
     The author inventor, also has to invent a suitable aphorism, to write along with:
         ‘When there is a thunder storm, rain or hail, a mansion may await . . . yet a shelter had to be found, even if a doll house.’

CROSS REFERENCE TO RELATED APPLICATIONS

none.

FEDERALLY SPONSORED RESEARCH

none.

SEQUENCE LISTING

none.

BACK GROUND INFORMATION

The embodiment of invention is directed to plurality of mechanicaldevices and their utility methods for emergency salvage of a blown outoceanic petroleum oil well, incorporating means of not only sealing theoil leak from the well bore (in conjunction with an immediate oil outlet system, set forth to optimize the mounting pressure within the well,and it's source of oil containment) in an effective and immediatemanner, but also resorting to emergency reparative process at thedistorted well head and beyond, that an optimal structural andfunctional state of the well is restored, stopping a ‘vicious cycle’ ofmere leak from a disrupted well turning to a spewing geyser into theocean.

There are innumerable petroleum oil wells bored into the ocean floor, byhighly evolved modern technological devices to tap such naturalpetroleum (gas/crude oil) resources. Many oil wells are clustered in theGulf of Mexico, Arabian sea and such oceanic grounds, often miles fromthe coast line, and as deep as a mile or more from the water surface tothe ocean floor, to find their way into the under ground oilcontainments, spread many miles in area. Oil is collected from the wellsinto surface tanks in moderate containers, or with ones as large asships.

The boreholes and/or shafts laboriously made in the oceanic floor to tapthe geological oil reservoirs is a modern wonder, which improved in it'stechnology over decades. The drilling of boreholes that form the tunnelsof the wells in the ocean ground are accomplished by innumerablevarieties of ‘Drilling Rigs’, a drilling rig being defined as an unit ofequipment built to penetrate the superficial and/or deeper aspects ofthe Earth's crust. The rigs can be built as small and portable to bemoved by single person, or they can be enormous in size and incomplexity of functioning so as to house equipment used to: drill oilwells; sample mineral deposits that can impede functional units;identify geological reservoirs; install underground utilities. Largeunits (rigs) generally configured as more permanent land or marine basedstructures in remote locations are also facilitated with living quartersfor laboring crews involved in well construction, at times hundreds innumber.

Hydraulic rotary drilling—this rotary system is utilized in oil welldrilling, and it's main break through came when Anthony Francis Lucascombined the use of a steam driven rig and of mud instead of water inthe Spindle top discovery well. Drill technology advanced steadily since19^(th) century, though there are several basic limiting factorsdetermining the depth to which a bore hole can be dug. All bore holesemploy inner ‘Casing annulus’ during construction of the bore tunnel ofthe well leading to the under ground reservoir. The casing annulus is ahollow sheath which protects the hole against collapsing duringdrilling, and is made up of metal (steel) or PVC (polyvinyl chloride, athermoplastic polymer constructed of repeating vinyl groups having oneof their hydrogen atoms replaced with chloride group. It is third mostwidely produced plastic extensively used in construction because it ischeap, durable, easy to assemble, and suitable for flooring and roofingmembranes).

The bore well has a nested configuration, that is, it narrows down as itcourses into the deeper layers of the earth's crust, because the solidmetal/PVC annuli of casings used to line the tunnel are built to beprogressively smaller as the digging gets deeper. The standard casingsare usually 40 feet (13 meters) in average length, and available in 14casing diameter sizes, spanning 7-30 inches in outer diameter.

Most drill holes deviate from the vertical, a phenomenon of practicalimportance. The forces operative in the unavoidable causes of suchinclination of the drilled bore wells are:

-   -   1. Reaction to ‘Foliation’—Foliation is the natural planar        fabric present in rocks, and is typical of orogenic belts,        affected by regional metamorphic compression,        -   and that property of the rocks to be encountered while            boring the ocean's earth crust invariably deflects the            vertical course of the bore hole, unless any modern            technology is set forth in place to counteract such axial            vertical deviation.    -   2. The torque of the turning drill bit working against the        cutting face (drill bit is a device attached to the end of the        drill string that breaks apart the rock being drilled).    -   3. Refraction as the drill bit moves into different rock layers        of varying resistance.

Oil well drilling commonly uses a process of controlled deviation called‘Directional Drilling’ (when several wells are drilled from one surfacelocation).

The drilling and production of oil and gas from the earth's mantle inthe oceanic floor is shrouded in risk and great hazard to the naturalenvironment that includes both marine life forms, and the terrestrialeco system adjacent. The many hazards, to list a few, include ignitionof the entrained highly inflammable gases like Methane causing dangerousfires, and the risk of oil spewing and polluting sea water, and such twoman made calamities at the same time can be uncontainable with availableresources, and utterly devastating to the healthy existence of theearth's planetary life forms. For these reasons, error proof safetysystems in under water bore well digging, and highly trained personnelare required by law in all countries, engaged in significant oilproduction. Despite such stringent laws, system failures andcatastrophic results did occur historically (and still occurring),though derived remedial measures through each ‘adverse-event experience’uniquely different from the other in some form or other, are stillnascent, and less than perfect.

Recent event in the gulf shores of Mexico involving BP oil company's oilwell (Deep Water Horizon) under construction, where in, the ignition ofentrained methane gas and it's fire that continued unstopped as long as36 hours, resulted in collapse of the surface structure of the oil well,and ever increasing oil gusher from the source. Several differentattempts by BP's technical team to contain the spewing geyser fromfinding it's way into the body of water and into the gulf shores hadfailed, mostly due to the inherently limited robotic attempts involvedat a moderately deep aquatic habitat.

In prevailing oceanic climate of the oil wells, after the bore wellstructure is disrupted, the sea water continuously gets into the oilwell, where as, the oil rises to the surface, because of the relativedensities of each, that could be contributing to the spewing of the oilgush at a later time, while it would be only a spill to start with.There would be churning forces set forth at the land mark area of thedisrupted bore well surface, the sea water trying to get in, while thelighter petroleum/crude oil is trying to get out. As the ocean waterforcefully fills (the hydrostatic pressure involved getting higher,proportionate to the depth of the sea floor from the surface) the underground oil containment space, the pressure will rise more and more insuch oil containment in a very short time, forcing the lesser dense oilto progressively rise into the ocean like an eruption.

Accordingly, it is imperative that immediate action be taken to containthe leak, and stop the sea water pouring into the containments of theunder ground reservoir—that will effectively dampen the rising pressureswith in that confined space, further resulting in reducing the spewingforce of the oil gusher—thus breaking the vicious circle. By observingwhat happened following BP oil company's Deep Water Horizon oil wellblow out, it is understandable that what ever precautions were observed,they failed, or did not stop the oil spewing into the surface waters.The calamity in the gulf shores happened before ‘Production Tubing’ andthe ‘Production Packer’ were installed, and the wide ‘A’ annular spaceacted as the tunnel for the oil gusher. Further more, the well behavedlike a very high volume well, probably as a result of sea waterprogressively finding it's way into the oil well, and the oil in turnrising to the surface, due to absence of the down hole safety valve(DHSV), which is usually placed in the ‘Production Tubing’ (the valvebeing a last resort to contain the leak from a disrupted well) as farbelow the surface as deemed safe, to be unaffected by any events leadingto wipe out of the surface well head platform.

As any unforeseen adversity can happen any time before completion of thewell to its last functioning detail, safety measures to weather off theunforeseen events at any step of the construction has to be in place,before beginning to undertake such operation.

The following embodiments are structured to counteract the events when a‘fire-blow out’ of the well head platform destroys any of the securitydevices before the well completion, the timing of the event exactlysimilar in timing of BP's ‘Deep Water Horizon’ i.e. before the‘Production Tubing’ and the ‘Production Packer’ are installed, OR inhigh production wells not destined to incorporate a production tubingand production packer, when the whole annular space (A annulus) is usedas the production conduit.

The inventions here in disclosed are directed to prevent and alleviatemany problems discussed above—and prevention of mere spill of oil/gasturning into a spewing geyser—by emergency sealing of oil leak fromcrumbled well head, and salvage of the top of bore well and the rest ofthe structure to safe functional status. It is not intended or impliedthat the originally planned structure is restored (as the originalstructure is altered, though only minimally), but functional order isdefinitely emphasized and resulted, how ever, different from theestablished norm. Such differences are being practiced on a regularbasis even in the oil industry (example—some high production wells arestructured to operate with out any ‘Conduction Tubing’ or ‘ConductionPacker’ incorporated with in the casing ‘A’ annulus). But the undeniableincentive to accommodate such ‘difference’ from the practicing ofrigorous standards in such industry where it is justifiably warrantedis—it's ability to weather through a calamity with catastrophicconsequences, even in situations where rigorous standards were followedthrough out the well construction, and later during it's maintenance—aclassic example that the ‘forces of nature’ are not always necessarilycontained through rigorous standards, and what seems like a ‘difference’may work to contain and calm down an occurrence of calamity.

Every effort was made to devise and describe the following inventionswith the best rationale, and the available information at the time ofthis writing. How ever, the author inventor is neither legally liable,nor personally responsible, for any inadvertent errors or omissions, orfor any consequences from application of the structural and proceduralinformation, as based on many past experiences, many inadvertent andunforeseen consequences were/are inherent to such ventures as deep seaexplorations and the like, shrouded in danger and never ceasing mystery.Accordingly, application of this disclosure in different situations,innumerable and unique is a personal choice. Further, understanding,analyzing, and adapting to unexpected individual situations still remainas the professional discretion and responsibility of the involvedcompany and it's associates participating in the day to day practice inimplementation of this invention, in part or as a whole.

BRIEF DESCRIPTION OF THE INVENTION

The embodiments of inventions here in disclosed are directed toemergency devises and their functions, to not only effectively seal anoil gusher from a blown out oceanic petroleum oil well, but also toestablish an immediate and effective oil out let system, set forth tooptimize the mounting pressure within the bore well and it's source ofoil containment, the bore well being complete or yet to be complete init's structural mandates, such inordinate function effectuated bydevices working in synchrony to achieve ultimate results deemed optimaland lasting. The disclosure is inclusive of reparative devices and theirmethods at the well head and it's vicinity, when such structures aredisrupted. The disclosure further enumerates structural measures for anemergency rig salvage during catastrophic event that envisions anEmergency detachable island rig, and also methods for preventing giantgas bubble formation at the source, so as to keep the rig from being avenue of danger, difficult to be contained.

The List of the Nature of the Inventions— The Emergency Sealing, andStabilizing Devices of the Blown Out Oil Well:

-   (1) (a) Emergency pneumatic sealing ensemble (EPSE): being the    prototype, devised both as a ‘more involved design’ (the EPSE unit),    and a simple design, as in a ‘Simple Sealing Ensemble’ (SSE),    -   (b) The emergency oil connecting and stabilizing unit (EOCS        unit) of the EPSE device,-   (2) The emergency stabilizing unit incorporating a well head    (ESUWH), at the well surface, and made of heavy weight metal    (steel), to stabilize any sealing device.-   (3) Emergency plugging oil conduit (EPOC),    The Emergency Preventive and Reparative Devices, and their    Methods—at the Well Head, and Beyond:-   (4) Emergency Isolation Platform (EIP) of the well surface, with    devices incorporating a well head,-   (5) Emergency Detachable Island Rig (DIR),-   (6) A model of oil gas separator (OGS) beyond the well head—to    mitigate Blow Out Preventor (BOP) failure—structured for preventing    a giant bubble of inflammable entrained gas, causing rig fire.-   (7) Threaded instant joint structures.

The Emergency Sealing Devices of the Blown Out Oil Well Bore—

(1) The Emergency Pnuematic Sealing Ensemble (EPSE)—

The prototype embodiment for an Emergency Sealing of a disrupted oceanicpetroleum oil well is an Emergency Pneumatic Seal Ensemble (EPSE),functioning as an emergency seal in the well bore of the leaking oilwell, within hours, with no wait time, along with an incorporated oilconduit and buoyancy stabilizing components—is the most important andcost effective device for immediate measures. The ensemble is structuredboth as ‘simple’ (the SSE), and ‘more involved’ (the EPSE Unit)designs—to be used in the settings of non disrupted and disruptedinteriors respectively, of the innermost casing of the bore well.

It is a preferable device in wells under construction, when the casingis completed, but ‘production tubing’ and ‘production package’ not yetinstalled, where in, it's innermost casing forms the annulus of concern(the A annulus) for effective sealing (example—BP's Deep Water HorizonOil Well blow out).

(2) The Emergency Stabilizing Unit with Well Head (ESUWH)—

An additional embodiment, The Emergency Stabilizing Unit with Well Head(ESUWH), an invariable accessory to the fore going device 1 (the EPSE),encompassing a simple heavy weight table like metal (steel) structure,having outwardly spanned out four legs with gradually widening bottoms,drilled into the sea bed, and cemented. Being a simple structure, it canbe installed swiftly on the sea floor, even by robotic instruments. Thecircular aperture in the thickened and elaborated center of the tabletop design accommodates well head-like structures with oil conduit thatis connected with the EPSE stationed in the well bore, as an emergencymeasure. Further, by it's sheer weight and cementing to the sea floor,it counteracts and overcomes the buoyant effects of the EPSE device.When an EMERGENCY ISOLATION PLATFORM (EIP) at the well surface describedin the subsequent section (4) below is constructed, the well headstructures can be transferred to/incorporated into the EIP platform, tocontinue similar functioning.

(3) The Emergency Plugging Oil Conduit (EPOC)—

The Emergency Plugging Oil Conduit (EPOC) is yet another embodiment thateffectively plugs the ‘production tubing’ of a fully constructed oceanicoil well, if the production tubing is fractured (with linear or circularcracking), or partially or completely severed by surface blow out of thewell. Such damage to the production tubing is usually located near andadjacent to the well surface.

The Emergency Preventive and Reparative Devices, and their Methods, atthe Oil Well Head, and Beyond—(4) The Emergency Isolation Platform (EIP) of the Well Surface withIncorporated Well Head—

Yet another embodiment specifying modified structural model of a deviceand a constructional model for installment of the said device, anEmergency Isolation Platform (EIP) with incorporated well head, anensemble erected at the crumbled oceanic oil well surface, as a means ofpermanent reparative structure.

(5) The Detachable Island Rig (DIR)

When a permanently configured marine based rig and it's oceanic oil borewell structure crumble, efforts directed to damage control, andrestoration should be immediate INSTALLMENT OF CONDUCTION TENSIONER, ANDDRILLING CONDUCTOR, if they are damaged, is the immediate measures atthe rig level, though not the initial emergency measures (as the initialemergency measure involves sealing the leaking oil well trough devices1, 2 and 3 of the foregoing). Their new housing rig of a basic structureis deemed to be fire proof, and at least in part directly operated byrobotic devices. The wreckage of the original rig is moved and clearedfor the emergency anchorage of the new one in it's place. A devisedEmergency Detachable Island Rig (DIR) in section-5 of this disclosure,novel and innovative, is deemed to effectuate immediate rig placement(with replacement of lost units in a shorter time), and urgentreparative process of structural and environmental damage pertaining tothe oil well, consequent to temporary/permanent restoration of it'sfunction. Replacement with the old yet functional rig in a shorter time,which otherwise can be a protracted process due to time, effort,finances, and personal needs/choices mandated in investing in a new rig,is of paramount importance, in the continuum of multitude of immediaterestorations.

Subject to fore going, a further embodiment, a Detachable Island Rig(DIR) is disclosed, enumerating the basic and schematic plan of adetachable island rig, even in permanently stationed off shore rigs,designed as complex and highly involved structures with any and allconceivable amenities.

Rigs can be permanently based in the sea, or floating with partialsubmersion, but permanent off shore structures are favored by oilcompanies due to the stable working platform of the rig. For the veryreason of it's complexity, the cost of equipment, and life/morale ofpersonnel involved, even a major part of the permanently based off shorerig should be an urgently detachable island from the ‘conductorplatform’ (stationing also a separate fire safety and fire fighters'crew in both areas), the possible site of the initial and ongoing fire,or explosion. Both areas are designed to be separated by a stretch ofsufficiently long fire proof corridor.

(6) A Model of Oil Gas Separator (OGS) Beyond the Well Head— To MitigateBlow Out Preventor (BOP) Failure, and Prevent a Giant Bubble ofEntrained Inflammable Gas Causing Rig Fire—

A Model of Oil Gas separator (OGS) Beyond the Well Head, is yet anotherembodiment encompassing basic structural and functional scheme designedto separate the large highly inflammable gas bubbles at the source, justbeyond the well head with failed BOP, and the devised structures areplanted in well vicinity, on the ocean floor. It is embodied with simpleyet highly utilitarian plan that separates petroleum gases from the oilat the source, and curtails inflammable gas explosions causing rig firesleading to mortality/morbidity, property damage, and pollution ofadjacent aquatic and terrestrial eco system.

(7) The Threaded Instant Joint Structures—

The invention also envisions that all future ‘Production Tubing’ or anymetal tubing (except the casings), involving the rig and oil wellconstruction be invariably built with deep inner or outer threadingthrough out, to immediately repair the damage by attaching a‘replacement tubing’ (with or with out nesting configuration of thearticulating ends), in case ‘fire and well surface blow out’ happenresulting in a ‘disconnect’ in the system. The ‘connecting joints’ shallbe configured in many shapes—I, L, U, C, J, T etc. in plain or in nestedconfiguration, and used as one or multiple joints at any place as needed(one or more ‘I’ joints are usually needed to incorporate other types ofjoint structures, to restore a conduit line, or complexinterconnections.

The Terminology Emphasized

The device and the description when denotes the terms ‘upward’, ‘up’,‘rear’ and ‘above’—they refer to the opening side of the bore well tothe ocean side, where as, the terms ‘lower’, ‘low’, and ‘below’ refer tothe ‘oil containment side’ underneath the ocean floor, the ocean floorbeing the earth crust underneath the depth of the water, through whichthe bore well is drilled. Further more, the leading/diving end, or thehead end of any instrument or device is the ‘lower end’ of that deviceor instrument in the bore well, being referred in upright position,where as, the rear end or the following end is the ‘upper’ end/side ofthat device or instrument, also being referred to it's uprightdisposition with in the bore well.

DRAWINGS

(1) FIG. 1: A schematic cut section-in-part diagram of an ‘Emergencypneumatic Sealing Ensemble (EPSE), in it's vertical disposition, showinga more involved EPSE design (the EPSE Unit),

(2) FIG. 2: A schematic diagram of a horizontal cross section of anEmergency Pneumatic Sealing Ensemble (EPSE Unit) showing structures atall strategic levels,

(3) FIG. 3: A perspective view of a joint articulation of air tubeconnections with a sliding screw arrangement,

(4) FIG. 4: A schematic diagram of an Emergency plugging oil conduit(EPOC),

(5) FIG. 5: A schematic diagram of the plan of an Emergency IsolationPlatform (EIP) of the well surface, with devices incorporating a wellhead,

(6) FIG. 6: A schematic diagram of the design of an Emergency DetachableIsland Rig (DIR),

(7) FIG. 7: A schematic diagram of an anchoring model of a detachableIsland Rig (DIR),

(8) FIG. 8: A schematic diagram of a model of oil gas separator (OGS),beyond the well head—to mitigate BOP failure, and prevent a giant bubbleof inflammable gases causing rig fire.

DETAILED DESCRIPTION OF THE INVENTIONS

The embodiments of inventions here in disclosed are directed toemergency devises and their functions, to not only effectively seal anoil gusher from a blown out oceanic petroleum oil well, but also toestablish an immediate and effective conduit of oil out let system setforth to optimize the mounting pressure within the bore well and it'ssource of oil containment, the bore well being complete or yet to becomplete in it's structural mandates, such inordinate functioneffectuated by devices working in synchrony to achieve ultimate resultsdeemed optimal and lasting. The disclosure is inclusive of temporary andpermanent reparative devices and their methods, at the well head, andit's vicinity, when such surface structures are either minimally orextensively disrupted. The disclosure further enumerates innovativestructural measures set forth for a rig salvage upon a catastrophicevent that envisions an Emergency detachable island rig, and alsomethods subject to disrupting inflammable giant gas bubble formationat/near it's source, the oil well, so as to keep the rig from being avenue of danger, for material, men, and marine life form, difficult tobe contained.

The devises listed and their functions briefly outlined in the foregoingsection are here in further detailed in sections 1-6.

(1) The Emergency Pneumatic Sealing Ensemble (EPSE) with an InvolvedDesign (EPSE Unit)—

It is an embodiment with an exemplary design, to be used with no waittime, and with in minutes of a catastrophic event, withdisruption/collapse of oceanic oil well head, and it's vicinity. Thedisclosure contemplates a prototype model made of strong inflatablevulcanized rubber device resistant to solvents of concern, likepetroleum analogs/sea water, inflated to desired size and stationed toseal the whole circumference at a suitable site, within the leaking borewell, to fully or partially stop the flow of the oil gusher, resultingfrom a damage to the original bore well structure, by what ever means,but mostly due to highly inflammable gas fire destruction/explosions.

Through an oil conduit with in it, the EPSE unit is connected to THEEMERGENCY OIL CONNECTING AND STABILIZING UNIT (EOCS UNIT) OF THE EPSEDEVICE that stabilizes the buoyant effects of the EPSE unit at it'sstationed position, and further serves as an oil conduit, that isultimately connected to the ESUWH device at the well surface.

It is also implied that a submarine robotic unit is stationed at thewell head soon after the catastrophic event that controls and monitorsthe functional and safety devices, such unit further improvised withcompressed or regular air chamber to supply air to the EPSE unit. TheEPSE unit is devised for situations when the blow-out happens while theconstruction is about to complete, as it occurred in BP's Deep WaterHorizon oil well, in which the ‘production tubing’ and ‘productionpackage’ were not yet installed, after the well casing was completed.Accordingly, the diameter of the leaking annulus (the innermost casingforming it's outer boundary), or the ‘A’ annulus, usually in a standarddiameter of 9 and ⅝^(th) inches—is the diameter of concern, that needsto be effectively sealed. The smallest EPSE unit is built with averagediameter of 8″ for effective passage, at times diagonally compressed tomaneuver through projecting obstacles if any, until it reaches the areaof totally preserved casement interior of the oil well, to be stationed,and further inflated for it's wedging. It is also available inhigher/lower corresponding diameters to be used in bore wells withhigher/lower diameter ‘A’ annulus, when higher/lower standard sizes areused as inner most casing.

The fore going historical back ground description of the subject ingeneral, discussed how most drill holes deviate from the vertical. Thestructural aspects of the remedial assembly, the EPSE device hithertodisclosed, is built to over come such axially oriented obstacles in it'slinear course of navigation into the drill hole, as the inventioncontemplates an easily maneuverable partially inflated/un-inflateddevice to pass through the drill hole, to be completely inflated in it'sstationed position.

The EPSE device is made of Vulcanized Rubber (polysulphide elastomer).Vulcanization gives rubber unique physical, dynamic, and chemicalproperties. The main polymers subjected to vulcanization arepolyisoprene (natural rubber), and styrene-butadiene rubber (SBR).During vulcanization some C—H bonds of the rubber are replaced by chainsof sulfur atoms. It gives properties of better heat resistance,flexibility without cracking, and elasticity and expandability like acar tire. Vulcanized rubber is insoluble in petroleum, and is used tomake gasoline hoses routinely used in gas stations. Vulcanized rubber isalso being abrasion resistant, apart from being resistant to solventattack (ordinary rubber is also very hard to be dissolved in anysolvent/medium. Naphtha, a petroleum distillate, is the only petroleumsubstance that can dissolve rubber when rubber is fragmented intosmaller pieces, and immersed in the solvent. The crude oil contains15-30% of Naphtha by weight, and lower than that amount when it isadmixed with sea water in a destroyed bore well). It is also to be notedthat all the bolt joints and assembly washers of rubber also usevulcanized rubber to specifically resist the degrading attack ofpetroleum analogs and sea water, both being solvents of concern in thissetting.

The depth where the EPSE sealer has to be stationed is variabledepending on the severity of destruction. Prior estimates by differentvideo and sonic devices are necessary to map the general configurationof the well structure for substantial distance in it's depth, to markout from what level onwards the cross sectional integrity of the well isstill preserved in it's entire circumference. It is the ideal level tostation the pneumatic sealer ensemble. It is of significance, because ofthe inherent adaptability of the installed pneumatically devisedstructure, a substantially complete and tight seal is expected,especially with the involved height of the pneumatic sealer. It has tobe further noted that any irregularities in the circumferential contourof the bore well in areas above it's stationed position will notgenerally impede the functions of the devised assembly as effectivegas/liquid sealer, and in ultimately preventing the leak at the wellhead.

The Emergency Pneumatic Sealer Ensemble (EPSE) is built with a projectedtotal diameter of the INFLATED pneumatic sealer to far exceed the borewell diameter, where it is stationed, for tight and secure wedging (asit is possible to be still functional when less than maximally inflated,but it is not possible to wedge the well diameter if it is the samediameter or less than the diameter of the well bore, at it's maximuminflation), but calculated to be below the ‘burst pressure’, withsufficient safety margin. In other words, it is workable erring in oversizing (yet in a size that would not impede it's passage), instead ofunder sizing. If there are significant metal projections in the entryarea, the device can be made leaner with strong compressive rubber bandsthat can be cut immediately after the obstacles are passed, as doingthis nearer to the surface is preferable.

FIG. 1 shows a schematic, cut-in-part sectional diagram of the EPSEdevice in it's vertical disposition. FIG. 2 further depicts thehorizontal cross sectional view of the EPSE device showing it'simportant structures at all strategic levels, and both views aredescribed simultaneously for better understanding of the structures awhole, and for the same reason, the corresponding function in relationto said structure is simultaneously described.

FIG. 1 depicts EPSE devise 2, having a generally cylindrical body 4except for spindling upper (or rear) end 6, and a lower (leading) end 8,that are dome shaped in their upper and lower surfaces. Both ends aremade of a strong rubber polymer relatively resistant to degradableaction of different petroleum analogs, one such preferable rubberderivative being vulcanized rubber (a polysulphide elastomer), which thewhole unit is also made of. The upper Dome (UD) 10, and the lower Dome(LD) 12 show structures heavily reinforced in their thickness needed fornatural thrust during navigation. FIG. 1 shows the upper dome (UD) 10having the exterior face of the flange 14 of a metal (preferably steel)spool 16 in it's center, with the central hollow 18 of the spool 16traversing the center of the whole thickness of the dome 10.

Both FIGS. 1 and 2 show the central part of the ESPE unit that houses awide bore steel tube (or an oil conduit, similar to the standard‘production tubing’ of the oil well) 22 that functions as EPSE body oilconduit of varying diameter (5-10 cms., similar to the diameter of thestandard ‘production tubing’) that is connected to the hallowedstructure 18 of the spool 16 of the dome 10, and the hallowed spoolstructure 24 of dome 12, on both ends, forming a continuous tube whichfunctions as petroleum oil conduit that is also continued as lower oilinlet tube 26 below the LD 12, and also as the oil out let tube 28 abovethe UD 10. The oil out let tube 28 has threading that compliments withthe corresponding threading of the lengthy ‘Oil Conducting andStabilizing Device’ (EOCS), that is to be attached to it, during themeasured navigation of the ESPE ensemble, into the bore well.

The oil connecting junction tube 28 is a large and sturdy pipe andstructured as a continuation of the tube 22 with the incorporation ofspool cylinder 16, and similarly, the lower end of tube 22 is connectedto the lower inlet tube 26 through the incorporation within, of thespool 24. Both the metal spools housed in the domes 10 and 12 haveplurality of joint bolts that pass through the whole thickness of thedomes, and secured to the exterior and interior flanges in correspondinglocations by metal screws. Such arrangement reinforces the metal andrubber joint apart from other conventional joining by rubber glue,contact cement etc.

It has to be noted that the domes 10 and 12, and the comprising upperend, and lower end of the EPSE ensemble are lesser in their diameterscompared to the rest of the body 4 of the device, and definitely lesserthan the known diameter of the bore well by few inches when fullyinflated, as it is intended that they maneuver through the well boredespite their thickness, and they do not generally contribute inexpanding or wedging, against the walls of the bore well.

The additional structures of the lower end dome member 12 are 3-4 metalpendulums 34 that are attached to the perimeter of the exterior flange36 of the dome 12, in equidistance. The heavy metal pendulums 34 add tosome of the required weight needed to thrust and navigate the deviceinitially in the bore well, and further, to counteract the buoyanteffects of the EPSE device 2 in it's stationed position in the borewell, when inflated. When fully inflated to wedge tightly, such wedgingof the EPSE unit against the walls of the bore well also counteracts tocertain extent the buoyancy of the pneumatic device. The EPSE can bealso built with out the option of the pendulums 34.

In situations like what happened in the gulf of Mexico, a CAP wasinstalled on the top of the well bore, but still a lot of oil wasleaking from gaps in the cap, because total seal is impossible, as canbe expected, with a rigid and totally solid structure, that can notaccommodate to the distorted contours of the encountered circumference.The EPSE ensemble, the instant invention, can be supplemented to thecap, or a structure alike, at a deeper level in the bore well,functioning in conjunction. If there is a large gap any where aroundsuch metal cap, big enough to maneuver the totally un-inflated EPSEsealing unit through it, it can be done. Other wise, the cap has to bepartially lifted to allow the EPSE pneumatic device to be introducedinto the bore well, and then close the CAP. After introduced into thebore well, it's navigation has to be a carefully measured and monitoredprocess, for a smooth descent, and also to successfully negotiate anysharp obstacles before it's designated stationing.

In accordance with the cut section of the vertical or the axialstructural scheme of the pneumatic sealer ensemble EPSE, of FIG. 1, theEPSE device embodies a sturdy but expansive rubber coat 38 which is thebodily continuum of the upper and lower domes 10 and 12 that togetherform the surface structure of the EPSE ensemble. As enumerated, the EPSEdevice as a whole is made of strong, sturdy, ocean hardy, and petroleumresistant vulcanized rubber that is expansive like a car tire, with inthe maximum thickness allowable for such needed expansion, dependingupon the whole size of the structure needed for such an expedition. Fewhours or days after a catastrophic event, the accumulation anddeposition of the globs of semisolid crude onto the uneven/sharpsurfaces if any, make the cave well of sojourn for the sealer EPSEensemble, not particularly forbidding, as it could be otherwise. It ispreferred that the expandable rubber coat 38 shall be like the outersurface of a honey comb, or any such configuration in it's surfacetexture, intended for a better grip on it's slippery base ofapproximation/stationing.

The embodiment further envisions that the rubber coat 38 that forms thepneumatic capsule is not a single cavity, but is made up of many smallercapsules 40, ranging about 6-8 in each of the two sets, the setspositioned as one above the other, arranged in a circular manner like awhorl (in it's cross sectional design), as shown in FIGS. 1 and 2,around a central oil collecting EPSE body oil conduit 22. The aircapsule(s) 40, are at least 2 feet in average length, giving an average5 feet total height to the EPSE device. Smaller and much larger sizescan also be made as per the need. Each air capsule 40 is roughlycylindrical or spindle shaped in configuration as viewed in a verticalcut section of the device, and is roughly oval shaped in it's horizontalcross section, being arranged as a member of a single circular rowaround the oil tube 22. The air capsules 40 are also made of veryexpandable vulcanized rubber. Of the two similar sets of circularlyarranged air capsules 40, the upper set 44 is adjacent to the domemember 10, and the capsule members 40 of the set 44 are attached to thelower free surface of the dome 10, at their upper ends. The lower set46, is adjacent to the dome member 12, and it's capsule members 40 areattached to the upper free surface of the dome 12 at their lower ends.The upper and lower sets 44 and 46 are separated by a membranousextension 42 extending horizontally through out into the center of theinterior from the surface coat 38. Accordingly, when any one or more ofthe air capsules 40 deflate by sustaining a puncture, it/they collapsetowards their attachments, above or below.

Each air capsule 40 has it's own tubular connection 48, that connects itto the air source. From the lower set 46 all the tubules emerge from theupper ends of the capsules. From the upper set 44 they emerge from thebottom. Both the sets converge over the membrane 42 to ultimately travelas a single bundle to be enclosed in a sheath of bigger non-compressiblevulcanized rubber tube 20 that travels out side, but in close proximityto the EPSE body oil conduit 22, and further, with and the continuationoil conduit of the outlet tube 28. It may temporarily dissociate asseparate set in places where the oil conduit tube has to be incorporatedinto the well head structures, to approximate again with the oil conduittube in it's further course, and it travels as far as needed to theplace of air pumping and air pressure monitoring unit. A second or thirdset of tubing can start where ever is needed, the individual tubesconnected to the corresponding tube by a secure articulation, bothsimilarly color coded. The tubes originating from the upper unit 44 ofthe rubber coat 38 can have color with wide bands, where as, the lowerunit 46 can have similar solid color for the correspondingly positionedtube members. The set travels in a weather resistant metal reinforcedvulcanized rubber (of polysulfide elastomer) hose, (with scatteredrubber eye lets for needed anchorage) colored outwardly as RED thatreaches the air pressure monitoring unit. The member air capsules 40 canbe individually numbered that are matched as pairs with thecorresponding color (solid in set 46, or banded in set 44) of theirextension tubes, to precisely identify each member air capsule of thetwo sets 44 and 46, or it's extension tube out side the EPSE ensemble.

Articulation of first and second set of the traveling air tubes ofcapsule sets 44 and 46, if necessary, in the open and turbulent oceanwaters has to be carefully planned and done with due regard for correctarticulation as well as air tight sealing required of each. At anyarticulation site, the vulcanized rubber hose housing the tubularmembers enlarges at this point to be housed in a hemispherical metalstructure, or any suitable structure. The tubular members are fittedwith metal terminals that also enlarge in size, and have the colormatched numbers engraved on them for proper articulation with thecorresponding member of the second set similarly sized, and has colormatched number engraved. The enlargement of the tubes can be confined tothe walls with out involving the tube lumen, so that the tube lumen canmaintain uniform size through out. Such enlargement facilitates anyminimum of the optimally configured larger size needed for roboticarticulation. FIG. 3 shows such a joint articulation of the travelingair tube extensions of air capsules 40, with a sliding screwarrangement, typically suitable in this setting. Each of the tubing ofthe first and second sets of joint articulation have similar threadingexternally 50, 52, for a substantial length at their terminals. Asliding screw/joint bolt nut 54 having complimentary threadinginternally, and the internal diameter of a size that accommodates theexternal diameter of the first and second set terminals 50 and 52, is asuitable type of joint bolt in this setting. First the sliding joint nut54 is situated completely on any one of the articulating member, yetleaving it's terminal end exposed, as shown in the diagram. The terminalends 50 and 52 of the articulating members are snapped intoapproximation by needed design 56 in their ends. Now thesliding/screwing joint nut 54 is slid over to the other correspondingarticulating member by rotating movement through it's innercomplimentary threading, so that it covers equal length of either member50 and 52 of the joint. Doing one at a time after proper matching andidentification of the engraved numbers avoid mistakes and confusion. Therubber tubing 55 of the second set can start with in the metalenclosure. After the proper articulation of the terminals similar to 50and 52, of all the traveling air tube members of air capsules 40, thetwo hemispherical enclosures or any such suitable enclosure are/issnapped close, securing them inside. They are further secured tomitigate their opening, by metal bolts or eyelets locked by metal wiresby twisting through optimum length—both types of closures being able toresist undoing by turbulent motions of the sea water in adverseweathers. This type of articulation is effective at any joint of twosets of tubing, either by manual or robotic operation, except that therobotic involvement may call for enlarged structures for neededprecision. Such articulation at the outlet hose of the EPSE unit shouldbe possible, in case the hose at any level is broken. It can beaccomplished by the provision of an off-shoot of an additional by-passset, arising from the main emerged air tubes just out side the EPSEensemble, terminating as the standardized hemi-component of the joint asdescribed with reference to FIG. 3, but with a difference that it isusually sealed by a closed sliding bolt nut, to be replaced when needed,by an open articulating sliding bolt nut of a new hose, with it'scounter part hemi component. This hemi-component of the EPSE unit isformed by each forked air tube at this level that comes out of the mainunit to form an independent bundle, with a closed air circuit eachterminal being locked by a screwed cap, instead of another openarticulating member of the articulating hemispherical structure. At thetime of new articulation, the old dysfunctional air circuit is clampedat it's forked end. It is a provision also to replace any dysfunctionalor damaged hose for what ever reason. The described arrangement is onlyan accessory option, and not a mandate to the original basic structureof the EPSE ensemble. It can be understood that the old jointarticulation can also be disjoined outside the EPSE ensemble, for a newjoint, but the time and effort for dis-articulation is saved in thealternative of using a forked articulation. It is very important thatthe hose system has to be checked for the patency of all member airtubes, before the EPSE is installed, after the manufacturer alsocertifies such functionality.

All the air capsules 40 are guarded by automatic mechanical one waycheck valve 58 in the place where the tubes 48 enter the capsules. Thevalves allows air flow in only one direction, that is, towards the aircapsule from it's tubular connection 48, and closes shut in the otherdirection. It is a safety device that precludes the entry of liquid/gaspetroleum entering into the rest of the air circuit system if any one ofthe air capsule sustains a puncture.

It is necessary to deflate the air capsules 40 when the EPSE devise hasto be taken out of the bore well. It can be done by a simple plan. Theother end of each air capsule 40 is devised to be connected to a set oftubing 60, similar to the air tubing set, as described earlier and eachcapsular tubing is similarly color coded, and travel with them to theair monitoring unit in a different vulcanized rubber hose colored GREEN(with rubber eye lets scattered at places for needed anchorage). It hasto be noted that this air tubing set is not provided with any type ofmechanical valves. At the monitoring terminal, these tubes 60 are sealedor clamped, and kept as such until the device needs to be deflated.During deflation, the seal or the clamp is opened, when the air gets outof all the air capsules. It is imperative that the clamp of anypunctured capsule is not opened (as oil can find it's way into thissystem) until the EPSE unit is taken out of the oil well. The airescapes with some pressure from the intact capsules, as the air in thecapsules are under pressure.

The two rubber hoses 20 and 60 of the air tubing of the EPSE device canbe anchored to the oil conduit EOCS unit tubing (described in thefollowing section), as it is elongated. The metal eye lets that aredevised out side the air tubing systems in the form of rubber hoses 20and 60, can be tied to the EOCS unit at the places where it's snappinglocks are placed, making a twisting knot with metal wires through the Uof the locks. Such close approximation stabilizes and strengthens theair tubing system in it's sojourn through the well bore. The air tubingsystem is made of flexible but tough uncompressible rubber tubing,housed in rubber hose, which itself has thin metal helical in the wall,to be maintained as diagonally uncompressible).

Pressure monitoring for each air capsule 40 is separately done, and whenthe sealer EPSE ensemble is stationed in a suitable place, all capsules40 are filled to equal optimum pressure, that was previously calibrated,and asserted that the assembly as a unit is definitely enlarged todimensions that far exceed the dimensions of the bore well, how ever,far below the attainable maximum pressure, which is separated by ‘burstpressure’ by a reasonable safety margin. Such built in dimensions andprior pressure calibrations allow member(s) 40 of air capsule(s) to befarther expanded and take over the space and volume of a lost member, byaccidental puncture, making no significant loss in the surface contourof approximation. When a single member is lost by gradual leak orexplosive burst, it will be reflected in it's pressures, as gradual orprecipitous fall respectively. When there is a gradual fall in onemonitor, all the monitors are to be immediately observed to note ifthere are two more gradually falling in their pressures, but after alapse of time. These are the two adjacent members that are losing thepressure due to loss of surface tension, but not air volume. They can bedifferentiated by their ability to build back their pressures by pumpingmore air, where as, it is not possible with the member that waspunctured. When such situation is encountered, the two adjacent capsulesare to be expanded to their maximum allowable pressures, so as theyeffectively take up the partial or total loss of air volume and correctthe gaps in contour created in the upper or lower unit. If there is agradual or precipitous fall simultaneously in more than one air capsule,it denotes that the damage is not localized, and that a wider area withpuncture to multiple air capsules 40 is involved.

Devising the EPSE with upper and lower sets 44 and 46 of air capsules isto maintain the inflated surface contour of the device as a whole, as atleast one capsules in a corresponding position may escape puncture in anoccasional rough sojourn through the bore well. Plurality of capsulesare designed for preserving the over all structural integrity of theassembly, though building separate tube for each unit is structurallytime taking, and monitoring each unit is labor intensive. How ever, thedetrimental consequences of the related calamities call forth for moreinvolved design, and diligent monitoring techniques.

The disclosed EPSE device may not be limited to the described structure,and any other creative additions can also be added to the basicassembly. Additional set of un-inflated members 62 can also beincorporated with in the device in reserve, to take over the place ofthe lost capsule in the same place. This can be done by devising eachtube to be having two separate lumens that bifurcate at the level of theair capsules to establish connection to the inflated and the un-inflatedreserve capsules separately. Both the capsules are similarly structuredwith provisions of the valves 58, and deflating tubes 60. The lumens ofthe tubes similarly bifurcate at the air pressure monitoring unit, andthe lumen of the un-inflated reserve capsule is temporarily clamped, andopened only when it's inflated counterpart is punctured. It may be notedthat through puncturing of it's counterpart, the un-inflated member willnot establish connection to it's luminal system, for the simple reasonthat the two luminal systems are practically separate through out,though structured as a conjoined tube, except at the bifurcations atboth terminals, and this structurally separate unit is simply not used,meaning it is not air inflated, until subsequently when needed, in oneor few of it's members. The members of the reserve sets 62 are attachedto the central partition 42 of the EPSE device, and after theircorresponding inflated member collapse towards the upper dome 10, themembers of the upper reserve set expand above towards the upper dome 10,where as, the members of the lower set expand below towards the lowerdome 12. The air tubules of the previously (first) inflated capsules arecoiled like a telephone cord at their entry into the air capsules, toallow their movements towards the domes 10 and 12, as theircorresponding new members are expanded by inflation, to take theirposition. The bifurcated tubes corresponding to the air capsules 40(attached to the domes) at the air monitoring terminal are strikinglythickened, to differentiate as the first set to be inflated, as they arealso similarly color coded, like their conjoined counterparts. Thereserve unit is also an accessory option, and not a structural mandateto the basic structural unit of the EPSE unit. The whole EPSE unit canbe replaced also when ever necessary, if there is a puncture, withsignificant oil leak through loss of contour, while the well headsalvage unit is being still under construction.

Pressure monitoring of the air capsules 40 at the monitoring station canbe done by means similar to the manner done for an automobile tire. Ithas to be noted that it is possible to calibrate the optimum pressureranges as it is to be practically done, by connecting the whole tubingunit to the air capsules in the EPSE unit before hand, instead of tryingwith out the whole tubing unit. In the ocean, oil water mixture alsoexerts force from outside which is proportional to the true verticaldepth (TVD) of the future stationing location of the unit. It is thepressure the air capsular pressure has to over come while inflating, andit is optimized below it's burst pressure. Prior calibration to optimizethe needed air capsular pressure avoids second guessing the correctnumbers. The predetermined level as previously configured by theoperating personnel by prior air filling of the sealing capsuleassembly, and noting the pressure required to maintain desired dimensionof the seal in the bore well, are done consistent with the diameter ofthe bore well dug by the company involved. The hydrostatic pressure atany true vertical depth (TVD) of the bore well should be known, and itshould be artificially created around air capsules and the rubber coat38, and then the capsules are inflated to calibrate maximally inflatablepressure, and also burst pressure with acceptable safety margin. 6-8capsules encircling a central tube arranged in a circular fashion nextto each other, within the known inner diameter of the production casingis a typical practical model to also take into account the pressureexerted by adjacent inflated capsule structures. This calibrated valuesthrough known numbers of the well structure involved, (except the truevertical depth, but 2-3 possible depths near the well head can be usedfor calculation purposes, as at least one of them is going to reflectthe TVD that may be encountered) are configured before/during the wellconstruction, and should be readily available during an adverse event.Maneuvering through the joint articulations should also be practicedthrough robotic manipulations before/during the well construction. Thisis applicable to any type of EPSE device, either simple (to besubsequently described), or structurally more involved model, asdescribed in this section.

The company manufacturing the device can also predetermine the optimummaximum pressure, and burst pressure at different sub-sea TVD ranges,and the diameter ranges of the bore well in which the device can beeffectively employed. The maximum pressure allowed is also calibratedwhen 1 or 2 adjacent members are lost which in real setting isidentified by the color-number match of the tubing unit(s) subject togradual or precipitous pressure changes, and confirmed by sonarsurveillance if present.

Integration of sonar equipment and monitoring can be done by out sideequipment attached below and above the ensemble by any suitable means.

Experts skilled in the art of hydraulic engineering should be part ofthe team involved in such technical decision making. It has to beunderstood that device like this, needed in an emergency situationshould be already there, at least two, before a bore well constructionfor an oil well is started. The company should contact the manufacturersand notify the diameter of the well involved. The manufacturers have toindividually build the EPSE device with two domes of the EPSE device atleast 3-4 inches smaller than the involved dimensions, and theuninflected diameter of the body of the device to be 1-1.5 inchessmaller than the diameter of the bore well. The attainable size afterinflation should be substantially more than the ‘A’ annulus-diameter(the inner diameter of the production casing), as it is possible to lessthan maximally inflate, yet being functional by generating neededtension for sufficiently tight wedging. The EPSE device size is chosenproportional to the well size involved, in standard pre made devices.

The EPSE Devised as a Simple Sealing Ensemble (SSE)

The EPSE is also built encompassing a simple design, as single aircapsule enclosed in a rubber coat with rough textured outer surface,called as ‘Simple Sealing Ensemble (SSE), and it is more easilyexpandable, by virtue of it's single air capsule compartment, structuredsimilar to a typical air capsule in the previous design. It has onereserve capsule, also fitted with a one way valve, a single inflatingtube, and also a single deflating tube. The device as a whole, isstructured like a car tire in it's cross section, but many times it'sheight (and with dome shaped ends), to cover sufficient vertical lengthin the well bore. It has a less involved design, and accordingly, is aneasy maintenance.

The air capsule to be ‘inflated first’ in the SSE—is attached to thelower dome, and expands upwards as it is completely inflated. Thereserve member is attached to the upper dome, and expands downwards, totake the position of the punctured and collapsed member, that waspreviously inflated. Because of it's well guarded position underneaththe upper dome, the reserve member is protected against any of thesurface trauma of the EPSE unit, and most likely to stay intact, ifneeds to be inflated in the destined position of stationing. Because ofthe limited number of the connecting tubes involved, all of them,including the deflating tubes, can have different colors and travel inone rubber hose to the air monitoring unit. The detailed structures ofthe first and the reserve capsule members can be compared to thedetailed structure of an individual air capsule in the previousembodiment of the more involved design of the EPSE ensemble.

For oil wells with no injury sustained to the interior of the inner mostcasing, the SSE can be a suitable model, and should be the chosen designfor it's less time taking installment, and simple monitoring techniques.The central oil conduit is identically structured, and air inflating,pressure monitoring, and further, the air deflating are similarly done,as in the previously detailed EPSE unit.

The Emergency Oil Conducting and Stabilizing Unit (EOCS Unit) of theEPSE/SSE Devices

The Emergency Oil Conducting and Stabilizing Unit (EOCS Unit) is anembodiment of an accessory device, that stabilizes the EPSE/SSE deviceagainst it's inherent buoyant effect, and further connects it to thesurface structures. The EOCS Unit is made of segmented or straightconfiguration. Mechanical force from above is the best way ofstabilizing the pneumatic device, any where in the bore well. Thecentral oil pipe as in the EOCS unit, if made heavy, can achieve thepurpose, if it also is secured by surface anchorage. The pneumaticdevice ensemble of EPSE/SSE unit with in itself has few feet of oilconduit pipe 22. Further lengthening as needed, can be added as 2-5 feetsegments, such segments made of heavy duty steel. Tubing similar to‘production tubing’ in it's structure can also be elected in suitablesettings, when the bore well to be navigated through is straight, and nosignificant obstacles need to be maneuvered through.

Each segment that is progressively attached to the EPSE/SSE unit isconfigured to be of metal tubing with threading on both ends thatarticulates with adjacent metal tube segments with complimentarythreading. They are tightened with rubber washers, and locked througheye-let holes of both segments that approximate when the two tube unitis completely tightened. The eye let joint is secured by tight snappinglock similar to the one used in daily use for locking suitcases, shelvesetc. 2-3 such snapped locking around the circumference in equidistance,for each two segmental joint can be very quickly accomplished even byrobotic devices. By successive additions, one at a time, of the aforedescribed segments, the tubing shall be progressively lengthened to thedistance where the EPSE/SSE is required to be stationed. The individualsegment members can be chosen as long as possible, for easy and rapidelongation. After the EPSE/SSE device is stationed at the destined depthin the bore well, the last segment is added, which is configureddifferently, that after it's emergence from the well bore on thesurface, the tubing shall have an additional outer sleeve that expandslike a trumpet, typically to a diameter of 9 and ⅝^(th) inches, withneeded configuration similar to the inner most casing, to associate withand hung to a well head-like structure, fitted in the EMERGENCYSTABILIZING UNIT WITH WELL HEAD (ESUWH devise, to be subsequentlydescribed) on the well surface. The inner oil conduit of the EOCS Unit,of 5-10 cms. diameter, can terminate with structural configurationsimilar to the standard ‘production tubing’, to be connected at the wellsurface, to a newly devised well head-like structure.

The place and depth where the EPSE/SSE unit has to be stationed aremapped with sonar and video devices, and the depth accordinglymaintained, by the addition of the needed tubing that are alsomeasurable. With each segment as big as 5 feet, the EPSE/SSE unit tendsto progress in a linear or curvilinear course, in it's navigation withinthe bore well.

The rubber hose/air tubing of the EPSE/SSE device can be anchored to theoil conduit EOCS unit tubing as it is elongated. The metal eye lets thatare devised out side the air tubing system can be tied to the EOCS unitat the places where the snapping locks are placed, making a twistingknot with metal wires through the U of the locks. Such closeapproximation stabilizes and strengthens the air tubing system in it'sfurther course from the EPSE/SSE device.

(2) The Emergency Stabilizing Unit with Well Head—Like Structure(ESUWH)—

The prototype embodiment of an ‘Emergency Stabilizing Unit with WellHead—like Structure’ (ESUWH) stabilizes and sustains the EPSE/SSE devicewith the EOCS unit in conjunction, in the stationed position with in thebore well, and can be further instrumental in overcoming the wellpressure the EOCS/SSE unit can not resist, by also incorporating an oilout-let system, and a well head-like ensemble, necessary inoptimizing/resisting the well pressure. Such embodiment is a heavy,weight stabilizing device, made of steel, and many tons in weight,depending upon the dimensions of the bore well, structured like a roundtopped table, with spread out and wider based legs (3-4), stabilized bydriving holes into the sea bed, and secured by cement. It's top has acentral hole in which a structure similar to the top of the first casingcan be detachably incorporated in a design resembling a flat plate, or ashallow basin securely hung through the hole. In this, a well head likestructures can be installed and an oil conduit coming from the EPSE/SSEunit and continued as EOCS unit, or the Emergency plugging oil conduit(EPOC, to be subsequently described) can pass through, (whosearticulating configuration can be structured similar as the component ofthe ‘production tubing’ that passes through the well head) to be hung tothe ‘tubing hanger’ over the well head. If the lower segment of theriser is damaged, distorted or displaced by fire/explosion, and by allmeans dysfunctional proving to be an impediment to the plannedstructures, it needs to be first dismantled, and taken out of the way,to be replaced very soon, for more permanent reparative process. Byprecise measurements of the extent of damage at the well site, the ESUWHcan be sized to be precisely incorporated into the structure of thecement platform further constructed, as described in the followingsection 4 (the concept can be better understood, read in conjunctionwith the section—4).

It is not labor intensive to install ESUWH, and it can be quickly doneif the riser at the well surface is dismantled. Such foot holding withthe three/four legs spreading away from the well area avoids disturbingthe well structures during it's installment. The center of the devisedtable top of the ESUWH with a circular passage hole within is thickenedor elaborated, to house and stabilize the components needed for wellhead-like structures. It is installed by robotic devises at the oceanfloor, as needed manipulations are less complex. The ESUWH device can beoriginally structures as 3-4 peripheral pieces of similar size andconfiguration with legs incorporated, and a separate circular centralpiece (that is configured to embody the top of the first casing), thatcan be assembled on the ocean bed over the well surface, by any methodfeasible and secure. It is configured to be smaller than the base pieceof the drilling conductor to be installed very soon (if dismantled inall situations it is proved to be dysfunctional), as described in thefollowing sections. The incorporation of the ESUWH device, substantivelysuited as a metal frame of the cement platform soon to be constructed atthe well surface, is also described in the following sections.

(3) The Emergency Plugging Oil Conduit (EPOC)

This design of embodiment, a prototype of an ‘Emergency Plugging OilConduit’ (EPOC) effectively plugs the ‘production tubing’ of a fullyconstructed well, if the tubing is fractured, or broken by surface ‘blowout’ of the well. Such damage of the production tubing is usuallylocated near the surface. The situation is encountered in oil wellswhere a production packers may or may not have been installed. Insituation where a packer hardware is in place, as it stabilizes theproduction tubing, only surface structure of the oil conduit is usuallydisrupted. Such damage can be cracks with oil leak, fracture involvingsubstantial area of diameter, or a total disconnect. Most packers arepermanent and require milling in order to remove them from casing. If itis a retrievable packer it can be easily removed for re-completion. Incase of permanent packer involved in massive blow out and destruction ofthe well head, the production tubing is expected to be incompletelyfractured, or completely disconnected and distorted in it's shape,luminal configuration, and positioning.

Future models with threaded configuration can be easily closed with newconnection of oil conduit, but old models with plain tubing, andpermanent packers, the situation can be riddled with problems foremergency replacement, as well structures are distorted, and even otherwise easy restructuring like ‘production tubing’ replacement, can be metwith adversities.

Accordingly, as an emergency measure, the oil conduit production tubingmust be plugged, to occlude the leaks, and the new oil conduit createdwithin it's lumen has to be connected to the well head structureencompassing the center of the ESUWH, the easily installed table topdevice at the well bore surface. The EPOC is doable at a very earlystage when pressure in the oil containment is not built up, by sea waterfinding it's way into the reservoir.

As embodied in FIG. 4, the emergency oil plugging conduit (EOPC) thattemporarily acts as an oil conduit comprises a metal (steel) tube ofsmaller caliber 1-2 cm. smaller than the original ‘production tube’(5-10 cm. standard diameter), incorporating a rubber sheath outside, onmost of it's length. It is necessary that the upper component of thedistorted or fractured original ‘production tubing’ is completelysevered, and taken out of the way. The EOPC 300, is configured instandard variable lengths of many feet, to be passed into the requireddepth of the remaining lower component of the production tube 302, for areliable occlusion of it's open upper segment 304 through a substantiallength. The metal component 314, of EOPC 300 is made of steel. The lowerterminal end 306 of EOPC 300 is slightly narrowed and has rounded rim,for easy maneuvering in it's passage. The metal component 314 of thereplacement EOPC tube 300 is capsulated over most of it's length with astrong vulcanized rubber sheath 308 that is connected at it's upper endto an air source 310 through a very thin caliber but strong tubing ofvulcanized rubber 312. After the EOPC 300 is passed to a required depthinto the remaining lower segment of the production tubing 302, the outercapsule of rubber sheath 308 is inflated through the inflating air tube312 to completely plug the tube 302 across it's diameter through out thelength the tube 300 is passed in. After the full and required inflationof the rubber sheathing 308, the tubing 312 connected to the air source310 is clamped at it's well surface terminal all the time, to seal theair, except to optimize the pressure of the air in the aircapsule/rubber sheath 308 by pumping further air, if the neededcalibrated pressure is below optimum. Oil can pass up through the lumenof metal tube 314. At it's lower end 306, the tubing 314 is devoid ofthe rubber air sheath so as to ensure the lumen of the tubing 314 tostay patent, and not occluded by possibly ballooned tip of the airfilled capsule 308. The upper end 316 of the metal tubing 314 that isconnected to the well head like structures 318 of the ESUWH device isconfigured in a standard manner resembling a ‘production tubing’, neededfor it's articulation and to be hung to the tubing hanger above the wellhead. After it's emergence from the well bore on the surface, the upperend tubing 316 can have an additional outer sleeve that expands like atrumpet typically to a diameter of 9 and ⅝^(th) inches with neededconfiguration similar to the inner most casing to associate with a wellhead-like structure fitted in the Emergency Stabilizing Unit with a WellHead Like device (ESUWH device) on the well surface.

A standardized required calibrated pressure must be always maintained inthe rubber sheath of air capsule 308 for needed inflation, and effectiveplugging of the production tubing 302. As the production tubing isusually well supported by production packers at a lower level, thestability of the plugged structure 302 also stabilizes the EOPC tubing300 in it's stationed position, apart from the gravity, and a tightseal.

Very early plugging of the oil conduit accomplishes the most importantgoal of preventing the sea water finding it's way into the containment,causing dangerous pressures to build up, making every sealing maneuverat that time difficult or virtually impossible by solid or pneumaticdevices.

With plugging of the oil conduit accomplished, it is easy to concentrateon other reparative measures, as the well surface is also deemed to beclean at this time, with out petroleum/crude oil/gas contaminating thesea water.

(4) The Emergency Isolation Platform (EIP) of the Well Head—

EMERGENCY INSTALLMENT OF CONDUCTION TENSIONER, AND DRILLING CONDUCTOR isessential as soon as the rig and it's connections to the oil well aredestroyed, and dysfunctional. The structure of the base piece of theriser (the drilling conductor) is devised to be far bigger (average of50-60″) than the presently manufactured and available maximum size of30″, and inverted funnel shaped at the base, to encircle the destroyedleaking bore well, and isolate it from the rest of the oceanic bed sothat oil contamination of the sea water is prevented in the very outset. The wreckage of the original rig is moved and cleared for theemergency anchorage of the new one in it's place.

The above project is generally planned soon after the EPSE unit or theEOPC devise and ESUWH were effectively installed, and the oil leak atthe well surface is controlled. Robotic operation is simultaneouslyundertaken to find the extent of damage at the well head, if any. Itthere is an explosion at the well head, with fractures to the surfacemetal casings and disruption of the ocean floor at the well head, thecircumferential diameters of the disruption of the ocean floor allaround the well head are to be measured. The largest diagonalmeasurement of these values defines the ‘Diameter Of Disruption’ (DOD)of the ocean ground at the well surface. As well head structure isdisrupted, all the incorporated security measures are expected to bedysfunctional. As in the case of BP's Deep Water Horizon oil well, it isa situation with great danger slowly brewing in, as the sea water canfind it's way into the oil containment progressively mounting thepressure. Accordingly, it is prudent not to be swayed away by a falsesense of security when oil leak is not detected in the beginning, but itcan soon happen. For immediate isolation of the damaged well from thesurrounding ocean floor, and also to rebuild the damaged well head, itis imperative that an emergency installment of a ‘Conduction Tensioner’and a running of ‘Drilling Conductor’ be undertaken in the conductordeck. If the rig had collapsed, and the well head blown out, theconduction tensioner could have been destroyed, and there is adisconnection in the drilling conductor (drilling riser), or the leftover structures of the riser could have been swept away by oceancurrents. Even if only part of the structures are visibly damaged, it ishard to detect the invisible damage to the remaining structures.Accordingly, it is prudent that the riser be completely dismantled, anda replacement planned.

Clearing of the destroyed rig wreckage is first priority, with anchorageof a new rig that is fire proof, and be at least partly directed byrobotic devices for immediate needed basic operations. If the rig isconstructed with detachable island rig (DIR), designed to be having anadditional conduction platform, as described in the following section—5,the reparative process can be immediately started. This saves preciousand precarious time at this point. The dimensions of the novel design ofthe funnel of the base structure of the drilling riser is chosen to beabout 30-40″ wider than the largest diameter that defined the ‘DiameterOf Disruption’ (DOD) of ocean floor at the well head, and it should beout side the outer diameter of the conductor casing. Suchcircumferential intact ocean floor is essential to drill a hole into thesea bed 141, and then running the funnel tubular into the hole andcementing (143). It is installed on a reliable circumferential ground ofthe oceanic floor with further stable ground within, to construct thewell platform for installing a well head, and new reparative casing.

FIG. 5 shows a schematic model of the reparative construction at thewell head involving the remodeled device of the base structure of thedrilling riser. The part of the riser 140 at the bottom and cemented tothe ocean floor can be made as inverted funnel shaped with wider base142, and such structural modification of the bottom allows the rest ofthe drilling riser 140 to be in the old standard sizes, and further addsto it's stability. If the damage at the well head is significant, theintact solid ground 144, around which a new riser had it's footageshould be sufficiently wide to stabilize it. A ring 146 of heightenedcement platform is built with centrally extended roof 148, where in thenew casing 150 and a new well head 152 have to be stabilized (on astructure 147 devised to be similar to the upper end of the FIRST CASINGfixed in the roof 148, to accommodate the well head-like ensemble 152),bypassing the damaged structures 154, comprising tops of old casings157, and their adjoining structures. It resembles a circular room filledwith rubble, obvious or minimal and unobvious, and a REPARATIVE CASING(smaller than the smallest that was previously installed, in the set ofcasings 157) 150, and the oil conduit production tubing 156, passingthrough the center of the room, unaffected by the rubble 154 in theroom, both the structures 150 and 156 being suspended from the roof-likestructure 148 through the well head 152, though not supported by thedamaged floor 158 at the level of the original well head. The new wellhead 152 is now located in the roof instead of the floor (of such roomlike structure conforming to a rubble), where the original damaged wellhead was previously positioned. In essence, a platform-like structure israised through adequate and intact supporting peripheral base, toaccommodate a new well head 152, and it's associated structures. Furtherstrengthening of the platform is achieved by flushing the elevatedroof-like platform 148 with the sea floor at the periphery, by a ramplike sloping ground of cement 160 all around, in a circumferentialmanner, which also burrows into the sea bed in sufficient depth, by alsocementing a thick layering of slab to form such overhanging sea floorsufficiently covering some partial periphery of the funnel base, thatmay lack natural over hanging sea bed. Extremely funnel shaped andmodified reparative base structure of the drilling riser has to bedevised for such sure and unfailing foot hold on the sea floor, and tosupport the future structures, despite the damaged bore well area 158 atthe well outlet. Structural modifications of the replacement riser atthe base to accommodate such reparative process can be planned by neededfunnel-like extension structure farther down, like a sleeve cuff (thatforms the funnel 142), to accommodate a raised circular sloping cementedplatform comprising of structures 148 and 160. In wells where there wasa blow out, and a well leaking at the top, but no obvious damageidentified by reasonable search, a new precautionary reparative casing(having 1-2 strings) smaller than the innermost casing can be cementedin the usual manner with out the need of constructing a cement platform.Such casing can seal any possible leak into the ocean in the vicinity ofthe well, at a future date.

The above sequence of construction has to be carefully planned. Thecementing of the funnel base piece of the drilling riser is the firststep, and at it's periphery an overhanging sea floor can be created fora more secure base structure by cement suitable for quick setting in 3-5minutes, which is available as QUIKRETTE, Hydraulic Water Stop Cement(number 1126), a high strength material with quick consolidatingproperties even while wet, available as above or below grade strengths.The inverted funnel like base piece of the riser creates a tent likespace on the top of the well head. Manipulations of the robotic armsfrom the rig are necessary to create the cement platform describedabove. First, flexible steel metal sheets are wrapped around the metallegs of the ESUWH structure that was already installed. This forms thecircumferential boundary of the circular room like area ofrubble/damaged well surface that also encompasses the DOD that wasmeasured earlier. Cement slurry is poured around the metal sheets totightly pack the space around it, as far as the boundary formed by thefunnel base of the riser. This creates the area 160. At this juncturethe first string of the reparative casing 150 is passed through thedetachable table top, and hung to the tubing hanger. More of cementslurry is poured to create a roof over the scaffold of the metal tabletop structure of the ESUWH device, and further over any unfinished areaof 160 to flush with the roof, completely enclosing the structure 147similar to the first casing, the table top like scaffold, and what everstructures that are to be solidly fixed at this time. It further extendsto the very periphery under the rim of the funnel 142, to fill in thedug sea floor hole over the area 143, where the riser was originallycemented. All precautions are to be taken to completely and compactlyfill the whole of the space around the metal frame of the ESUWHstructure, and the funnel base piece structure of the riser.

If there is any well surface explosion, how ever severe, it can beassumed that the second string of any casing, and most importantly theinnermost casing (that is well bore deeper than 40 feet or 12 metersfrom the surface) is spared from any compromise, involving the inside ofthe casing. For that reason, the installation of the first string aloneof a New Reparative Casing can be reasonably assumed to be sufficient toseal what ever cracks or fractures that are inflicted to the inside ofthe damaged innermost casing. Video or sonar devices can be utilized tofurther confirm the presence of any cracks or fractures involving theinside of the inner most casing at this level (junction of the first andsecond stings). It not found, it can be reasonably assumed that theinside of the inner most bore well casing at level deeper to the firststring is completely intact. To cement the New Reparative Casing to theinnermost casing by filling cement slurry through the annulus, theconventional process can be employed, by circulating cement slurry intothe casing shoe, and the annulus, pumping through a plug anddisplacement fluid. At this time, the EPSE/SSE ensemble can be loweredinto the well bore beyond the depth of the first string, and it's oilout let tube 28 capped with metal cap having complimentary threading, sothat the cementing of the first string of the reparative casing iscompleted. At this time the EOCS unit of the EPSE/SSE is alsodisconnected. Having been stationed in the well bore for needed time tooptimize the pressure in the oil containment, it can be assumed that theEPSE/SSE device can be safely capped to temporarily stop the oil outflow. Pressure recordings with in the bore well, beyond the EPSE/SSEdevice can be also done by instruments passed to a deeper level, byslightly deflating the device, and inflating again.

If it is a EPOC device plugging the ‘conduction tube’ that was in placeas a sealing device of the leaking well, it needs to be completely takenout along with the whole of the ‘conduction tubing’ at this time, or the‘conduction tubing’ can be completely fractured at a level deeper to thefirst string, and in either situation, replaced by the EPSE/SSE ensemblestationed at this level as the well sealing device, that can be capped,so that the cementing of the first string of the New Reparative Casingcan be completed. In situations where fractures of the second string ofthe inner most casing is identified by video or sonar devices, theEPSE/SSE device has to be lowered below the junction of the second andthird string, and a second string of New Reparative Casing alsocemented. As the emergency situation was earlier weathered of, thesesteps can be carefully calculated, and executed even by means that aretime taking.

The above structuring of the platform already described, by no meansassume that the problem of sealing the well bore and the oil containmentis solved. It only effectively devised a platform for replacement of allvital structures. The oil or gas leak may be still possible from theburied rubble at the well surface, despite 1-2 strings of reparativecasing(s) being cemented, though such leak, by all means, is a remotepossibility. A second blow out is to be hundred percent ruled out inthis labor intensive restoration that can be riddled with fear andtrauma of past experience, and understandably invoking an anxiousanticipation at every step, how ever, aiming at the well salvage.Accordingly, it is prudent that out let pipes be embedded in the roof ofthe cemented platform, positioned out side the well head, so thatfurther spill if any, is let out, and not blow out the cement platformwhen sufficient pressure builds up. For that purpose, the out let pipesare fitted with one way check valve to only let out the oil/gascollected inside the cemented platform, from the real or imagined rubble154. With effective Cementing of the 1-2 strings of the New ReparativeCasing as a continuous bore well column, such spill, is deemed to benegligible. Two types of disposal are available to the oil/gas, possiblyemanating from areas 158 and 154, to be let out—

-   -   1. Very minute tubules 166, inverted J shape in configuration,        are studded in the periphery of the roof, fitted with one way        valves to only let the oil/gas out, but not to let the sea water        in. Their inlets are dipping into the room of rubble, where as,        their out lets are out side the cemented platform, thus        traversing the whole thickness of the newly constricted        structure. Because of their inverted J shape, with their outlet        terminals facing downwards, and located outside of area 148, any        hydrostatic pressure due to true vertical height (TVH) of sea        water at this level, and exerted on the one way valve, is        minimized. Spurts of oil/gas is let out with small pressures        built inside the cemented structure. Such spill into the body of        ocean is deemed negligible. How ever, samples of these spurts        should be monitored, to curtail even minimal danger to the        aquatic life forms, and the deep sea environment. They have to        be sealed or capped (the tubules being threaded in        configuration) in such threatening situation. (They can also be        capped, as long as the drilling conductor is in place, and the        well surface is isolated from the ocean water around, in which        case the following arrangement 2 is a suitable working        alternative.)

(The hydrostatic pressure of the deep sea in this situation isimmaterial, as it has no effect on the inverted J tubes, by virtue ofthe way their openings are positioned. It is for the reason—that onlythe height of the column of fluid vertically above any point of concernis what contributes to such hydrostatic pressure. Further more, thePascal's law (the pressure exerted at any point in a closed body offluids, is equally exerted at all points with in that closed space) isalso applicable in this situation, and the hydrostatic pressure at thetips of the inverted J tubules is not subject to hydrostatic pressurefrom any point in the adjacent body of sea water as a result of the TVD(true vertical depth) in an open body of sea water (as opposed to bodyof fluid in a closed space, or as in a situation where a tube has it'sopening facing upwards, and so having the effects of TVD).

-   -   2. A moderately sized tube 168 can also be embedded in the roof        of the cement platform with it's inlet opening into the space        154, and fitted with one way check valves at strategic places,        and the tube 168 courses up to be joining the main oil pipe, at        any suitable level. The valves allow only the out let pipe 168        to empty any collections of oil/gas into the main oil pipe. The        one way valves can be multiple (at the level of the cement        platform, and at the level of the main oil pipe), to improve        efficiency. This tube is inverted L shaped, it's horizontal limb        entering the main oil pipe at 90°. This makes the hydrostatic        pressure of the vertical oil column of the main pipe exerted on        the valve to be dampened. Mechanical forces set up for the oil        to flow upwards also help the entry tube to empty into the main        oil pipe, and not the other way.

Reparative Casing 150, smaller in diameter than the smallest availablecasings at present, should be manufactured, and available to those whoused the smallest available casing as the innermost. If not, smallersized casings are readily available for the rest.

Multiple Leaking Craters in the Ocean Floor

If oil leak at different areas of ocean floor is located as guided byhovering airplanes or air filled balloons, miniature pneumatic balloonscan be used to seal the ocean craters, and then permanently plug on thesolid scaffold formed by the pneumatic sealer, by structured combinationof metal mesh, and hydraulic water Stop Cement 1126 (QUIKRETTE). However, this is undertaken only after a permanent structure is built, butnot when the EPSE is in place, as such measure can possibly mount wellpressure below the stationed devise, making it unstable. Such spillageinto the ocean floor in many different areas are possible, only if theoil in the bore well is under sufficient pressure. How ever, withreparative permanent casing, and cement-sealing the areas of fracturedinteriors of the innermost casing, such craters are expected to losetheir connections to the oil well bore. The ocean body has to becarefully surveyed to spot the areas of identified past spillage, and atthis later date, they are not expected to be seen.

(5) The Detachable Island Rig

A drilling rig can be defined as an unit of equipment built to penetratethe superficial and/or deeper aspects of the Earth's crust. The rigs canbe built as small and portable to be moved by single person, or they canbe enormous in size and in complexity of functioning so as to houseequipment used to: drill oil wells; sample mineral deposits that canimpede functional units; identify geological reservoirs; installunderground utilities. Large units of drilling rigs, generallyconfigured as more permanent land or marine based structures in remotelocations are also facilitated with living quarters for laboring crewsinvolved in well construction, at times hundreds in number.

The rig as described, can be permanently based in the sea, or floatingwith partial submersion. Based on the cost of multiple equipments, andlife of personnel involved, even a major part of the permanently basedrigs should be constructed as a detachable island from the conductorplatform (stationing also a separate fire safety and fire fighter's crewin both areas), the possible site of the initial fire or explosion. Bothareas should be separated by a stretch of fire proof corridor.

The structural divisions of the rig under construction should becarefully planned, even if it is not planned to be a floating rig.Ground stability can be a factor in opting for a permanent base securedto the sea floor. What ever mode is chosen, there should be provisionsfor the detachable island of the rig to quickly steer away from theconduction platform, if the ‘fire or dangerous gas alarm’ goes off as awarning for the crew. The detachable island of the rig is based on thefact that there is no need for the whole rig to be destroyed, and whatever can be saved, should be salvaged, including all the personnel asone pack, working together for such steering off of the rig island.

FIG. 6 shows the schematic diagram of a plan outline of a rig thatincludes a Detachable Island Rig (DIR) with in it's structuring. On oneend of the rig is the Conduction platform 102 that also includes anappendage of a fire station 104 with the crew. The adjacent segment 106stations structures needed for immediate operation of the Conductionplatform. Structures 102 and 106 are connected to the rest of theDetachable Island Rig (DIR) 108 by a stretch of fire resistant corridor110, 10-12 feet long, that also harbors any tubing or wired connectionsto the island 108, all running on two sides of the corridor, one sidefor electrical wiring 105, and the other for any metal tubing 107. Allmetal tubes are preferably substituted by a short segment of suitablerubber tubing 109 at the junction of the corridor 110 and the island108. Every metal tubing in the rig has treading inside or/and out, forimmediate repair and articulation by ‘joint tubing’ devised in I, L, C,J, or T shapes having complimentary threading with straight or nestedconfiguration. The island rig 108 is detachable from the corridor 110and houses the costly and heavy equipment, supplies, needed reserves,working area 114 (having remote controls to the conduction platform,well head, and all functional and security devices), and living quarters116 for the crew. Such separation of the island area 108 from the fireresistant stretch of corridor 110 gives few minutes time for the island108 to escape from fire, and be detached and steered away from the restof the immovable part of the rig 102 and 106. The island rig alsoharbors a fire station 118 with crew, additional conduction platform 120(to facilitate an immediate reparative process) with a basic structure,to be fully equipped as needed (for immediate replacement andrestoration work, if the original conduction platform is irreparable),and a simple basic steering equipment with a powerful engine, in thefarthest end 122, similar to a small ship. Devices have to be in placefor the island rig 108 to be structured as permanent base structure, andyet to be detachable in fire or explosion emergencies. The island rig,as a whole, can be stationed on a cement platform 124 erected from thesea floor that behaves like a permanent base. It is most suitable if anystructure either in the fixed base or the DIR, like a room or wall, arepossibly designed to be easily dismantled, to be arranged into adifferent configuration as needed during the time of restructuring,and/or each unit can have a movable but temporarily fixed base. It hasto be noted that the schematic FIG. 6 only shows the possible plan ofthe rig, but not exactly the true shapes or exact dimensions.

The floor level of the concrete platform 124 is so structured that it isat a sufficiently low level from the water surface, so that the islandrig 108 can be steered over it to be stationed in a right position.Suitable mechanical devices have to be in place to overcome the buoyantforces of the DIR, to bring it down by few inches, to be rested on thesolid base of the rig for it's locking in position. A device of doublepulleys 126 as shown in FIG. 7, strategically positioned at multiplesites on the concrete base 124 of the rig can over come such forces bymaneuvering steel ropes 128 fixed to the ringed structures 129 at thesides of DIR 108 in corresponding positions and intervals. They can bepositioned at different higher levels also for the steel ropes to beoperated at any suitable level for exerting traction on the DIR 108 Adownward traction on the steel rope 128 on all the pulleys 126simultaneously will bring down the DIR 108 by few inches on to theconcrete/steel base 124 of the rig to be firmly stationed on it, indesired position. The under ground basement 130 of the concrete righouses similar devise of double pulleys 132 working in the oppositedirection, the movement of the terminal metal rope 136 being aided byelectrical forces of an electrical motor equipment 134. In this positionof approximation of the pulleys and the rings, the DIR is also in aposition for locking by remote controls. After locking, the steel ropesare detached from the rings of DIR. The underground basement also houseselectrical generators needed for the whole operation of the rig. Beinghoused in such under ground basement, the chances of the generatorsbeing destroyed by fire or explosion is minimized, as this equipment isthe ultimate ‘power house’ for survival off shore.

In a right positioning the DIR 108 can be locked by mechanism similar tothe car door (in magnified size with allowance for some imprecision inpositioning) by a remote control. These locks are multiple and arelocated all around the floor except the side 122, where the engine motorfor the rig steering in the water is located. Unlocking of the multiplelocking sites arranged in a row on the sides of attachments is done byremote control. The unlocking device is similar to the one used for thecar doors by a remote control device whose control buttons can bepressed one after the other in quick succession, all being alsocontrolled by a single universal button, for each side. Accordingly,three buttons for the three locked sides of the DIR 108 are operated forit to be completely detached from it's permanent base. With a fourthbutton, the starting engine of the steering station 122 is activated totake an automatic straight course away from the rest of the rig, untilthe steering control is taken over by the crew members for directionalcourse. Alternately, any mechanical anchoring devices currentlyavailable in the market can be used to detachably anchor the woodenfloor of the island rig 108 from the permanent base structureunderneath, and the permanent rig structure 110 adjacent. The DIR can beconstructed on a vertically adjustable platform, to conform to therising and falling levels of the sea water, so as to always maintainoptimum submersion of it's base structure in water. It can also bestructured to have wheels like those of a shopping cart to project atthe base when needed, for finer adjustment of it's positioning duringstationing on it's base platform.

At the junction of the fire resistant corridor 110 and the rig island108, a crash cart is equipped to disconnect any tubing 107, and wiring105 that connect the two areas 110 and 108. Each tubing or wiring isdifferently color coded and every member of the crew including the firefighters should know how to instantly disconnect or severe, and clamp orseal each tubing and wiring. The metal tubing 107 are made of shortsegments rubber tubing at this level. If they are coursing on the wall,the part of the rubber tubing should have a U or C configuration 109 foreasy clamping and cutting). The ends of each metal tubing 107 making theC or U junction, can have attached metal dampers to clamp (by mechanismsimilar to a tap) both ends of the rubber tubing before severing. Thewiring 105 on the either side is carefully cut and sealed. Working withremote devices as much as possible should be the priority to be stronglycontemplated, to minimize the tubing and wiring. The signal to unlockthe locking devices should be set by the key personnel carrying theremote control, as soon as the connecting tubes and wires are severed.Similar signal also activates the engine to speed steer the island rig108 in automated straight course, in a direction away from the immovablerig area. Big rolls of wet jute burlaps stored in reserve at differentlocations of the rig, and thrown on burning objects or equipment, orcrew members, is the most effective way of putting of fire, even frominflammable gases, apart from water and fire extinguishers.

If the island rig had caught fire before it's detachment, powerfulsprinklers spread all around, jetting water from the sea, should beactivated, and control of fire should be easier as the crew is movingaway from the source of danger. Rescue attempts from out side should beimmediately activated also. Life boats 138 are also kept in reserve onboard. They are positioned all around the periphery to be wheeled downby automatically projected sliding ramps 136 into the water,

The crew can move away as far as it is deemed safe, but continuouslyworking on the security and functional devices through remote control,and keeping vigilance on the expert professional fire crew left on thedeck. They can return to the original rig area as soon as the fire isput off, station the island 108 to start reparative process, using theadditional conduction platform 120. If the damage to the immobilestructures inclusive of the original conduction deck 102 is substantial,and can not be immediately repaired, quick surface demolition can bedone, as in this situation, clearing of the wreckage into the ocean iseasy and less time taking than a ground demolition. The DIR can be movedfarther on to the concrete base of the area where the fixed part of therig was located, so that the area 120 can be placed in the area of 102.In this instance the strategically placed locks in this area of the base124, may not be all around, but even one side is sufficient forstructural stability. The basement with generators should be diligentlyconstructed to withstand any calamity, so that immediate electricalcircuiting, is restored. Once the reparative casing is cemented, and theproduction tubing placed, using the new conduction platform, to restoreimmediate well integrity, any further structuring of the rig can be donefor ongoing well maintenance. Work needed in the rig area at this timeis not as demanding as at the time of well digging.

When it is clear by all means that the fire can not be contained byavailable techniques, and can only endanger the lives of the firefighter's crew, and staying back would not save the situation, everycrew member should steer away, and no body left behind. It is to thebest interest of the crew that every body gets basic training in firefighting, though few are experienced and highly skilled. Those skilled,and stayed back should plan to jump into the ocean in life threateningsituations, or when they catch fire, and dive in (to avoid surface oilor crude) for few seconds. The island crew should have powerfulbinoculars to keep vigilance, and as they steer away, they should letout some life boats into the ocean that are anchored to the stable rigplatform by lengthy ropes, so that the fire fighters who jumped into thewater can reach them. The boats should have water proof light source tobe located if the calamity happens after darkness. The rigs under groundbasement should also be housing some life boats located at itsperiphery. The life boats employed in this situation should haveprovisions for the ‘rescued’ to get in swiftly, as fire can be spreadingon water surface also. They should have two hanging ladders on one side.On the other side the hemi section of the boat is built much heavier tostabilize the weight of the person and prevent the boat toppling, as theperson tries to climb up. The boats should have wheels in the bottom toroll them into the sea from the sliding floor of the deck of the rigwhere they are stationed, so that the weight of the boat would notimpede the swiftness needed. The boat on the side of the ladders shouldbe painted with alternate black and white stripes (to aid approachingfrom the right side), where as, the rest of the boat is painted white,that helps enhanced visibility in darkness (it can also help the rigcrew spotting each other, and to be spotted by the rescuing crew),though the fire can also throw light into the vicinity. All the boatsshould also have fire resistant surface, secured oars inside, and snapsto instant disengaging of the metal rope to steer away from the rig.

Insurance coverage of damaged rig can be a factor in planning againstisland rig and it's salvage. How ever, familiarity with the parts of theold rig, remedial measures/damage control that can be immediatelyundertaken without losing precious time in an utmost critical situation,when such measures are easier, and most importantly, avoiding morbidityor mortality of the crew members—are the factors in favor ofconstructing a detachable island rig. Finding a new rig that fit's thecompany's immediate needs and options is enormously time consuming,causing indirect waste of money in such time lost. The insuranceagreement can be planned for covering the needed construction, parts,and repair, to restore the fullest and best functional state of thepartly damaged rig, as such undertaking is very cost effective for theconcerned insurance companies also.

Alternatively, the oil collecting system can be located at a safedistance from the rig, the tubing having a let out from the drillingconductor many feet away from it's connection with the conductionplatform. The oil collecting unit can be totally or partly operated byrobotic devices, and free from any non-electrical source of ignitionspark (where as, such source can be inherent to the rig, as a unit, towhere the inflammable gases should never find their way), which is abasic and most efficacious preventive measure, when all else canpossibly fail. The oil receptacles have to be constructed in such amanner (as simple mechanical volume reservoirs), if gas under pressureexplodes, any structure involved should not create an electric spark.The DIR is a last resort as there is still possibility that the gas, andthe fire, can find it's way into the rig, as essentially all the unitsare interconnected, as long as the drilling riser is connected to therig, and to the oil well.

(6) A Model of Oil Gas Separator (OGS)

This design of embodiment, a prototype model of an ‘Oil Gas Separator’to be situated beyond the well head and intended to mitigate BOPfailure, and prevent a giant bubble of inflammable gas causing rigfailure. Entrainment of highly inflammable gases into the oil collectionsystem, at times with unexpected force that can be difficult to contain,can burst open through BOP of the system any where, and such gasentrainment can be set on fire in the off shore rig, as happened in Gulfoil well. Separating the gas from the oil at the very source near thewell head, in case a big gas bubble escaped the sub-sea BOP, is the bestway to avoid danger from such unexpected entrainment of highlyinflammable gas reaching to the surface rig level, and setting up fire,by otherwise insignificant spark.

FIG. 8 shows such model which is simple in it's device and operation,and different from the basic model of flow control by a valve mechanism,because such ‘valve’ mechanism at times failed, and let out theinflammable gas, at the source. Though the valves are ingeniousinventions, in certain set ups, as in oil wells, at times with immensepressures not else where encountered, the valves inherently lackprovisions to ‘resist’ at these pressures. They are probably best suitedin oil conduits with narrow caliber as in a ‘production tubing’, as theenormous resistance exerted by the BOP most of the times, overcomespressure originating in such narrow caliber. How ever, when theinnermost casing is the oil conduit (a situation before well completion,as in Deep Water Horizon oil well, and in high production wells when ahigh flow is planned, with out a narrow lumen ‘production tubing’), theresistance of the BOP is against a pressure caliber of equal scale atthe well level, and of immeasurable scale beyond, from the wellcontainment under great pressure. Most, though not all of the BOPfailures probably happen in these circumstances. It can be compared to anarrow open door controlling entry, and a situation when flood gates arefully open, when onslaught is naturally through a wider dimension.Accordingly, it is prudent that yet another mechanism in conjunction bealso set in place to mitigate the resulting calamity. It has to berealized that the gas bubble of enormous size, and under very highpressure is the source of danger and has to be eliminated at the origin,from entering the oil collecting system.

The FIG. 8 shows the collection oil conduit tube 70 beyond the wellhead. This tube is structured to fork into 3-4 tubes 72 that lead intorelatively large tanks 74. Typically the bottom of each tank 74 isperforated with wide aperture sieve like holes 76 through out, where as,the top of the tank is fitted with two outlet tubes 78. The tankcontains small additional intact compartment 82 below the level of thesieved bottom, that also has an out let tube 84. As soon as the oil gasmixture/crude, or the gas alone enters the tanks 74, through the tubes72, the oil (semi-solid plus liquid crude) flows down from the tubes 72,and finds it's way through the wide perforations 76 in the bottom of thetank to compartment 82 below fitted with outlet tube 84, and iscontinuously let out by upward flow. The tubes 72 are structured to riseonly few inches (about 8-10 inches) from the bottom of the tank. The gasunder high pressures rises to the top of the tank to be led into surfacethrough two outlet tubes 78, into separate gas collecting system notlocated in the rig, and connected to separately devised receptaclesaided with provisions to deal with gases under high pressures. Theoutlet tubes 84 from all tanks join a single tube 86 at widely differentheights (to avoid further formation of a large bubble, as the gascolumn, if any, is invariably separated by intervening heights of liquidcrude) All tubing can travel upwards together as a single pack.

The tubes 72 are fitted with external control on/off devices 73 to stopentry of oil/gas into any tank, when desired. They can also control theoil inflow in such a manner, that the level 80 of the oil in the tank 74is kept below the terminal of the tube 72 in the tank 74, under usualcircumstances as shown in FIG. 8. For new wells with very high out flow,all tanks 74 can be operational. When the flow slows, only two can beoperational. When it needs to be operated by additional means to get theoil into the system from it's containment, one tank 74 may beoperationally sufficient, as the oil/gas can be well controlled with onetank 74, if gas bubble builds up, yet allows sufficient pressure forupward flow.

Each tank 74 is fitted with a spiraling churner 88, suspended from theroof of the tank, and structured in ‘inverted funnel’ configuration,being widest at the bottom, and moving up and down every few seconds,like a house hold kitchen mixture (mixer), that disrupts any semi-solidcrude collected, blocking the perforations 76. Depending upon the typeof the oil well and the nature of the crude, some constructions may notneed the churner 88, as what ever semisolid crude had passed up theperforations of the lower completion of the well, should be able to passthrough the bottom perforations 76 of the tank 74, with out blockingthem. The tube 86 mainly contain liquid/semisolid petroleum, or agas/liquid/semisolid mixture, but the gas in this mixture, if any, isforced to be broken/dispersed into small bubbles while passing throughthe sieve perforations 76, and further, the gas column formation, ifany, is also dispersed in it's course, instead of entering thecollecting oil conduit 86, and the off shore rig, as a hazardous giantbubble. There can also be optimum suction set to be operational, for theuplift of the gases entering the tubes 78, that can just counteractotherwise gas suction into oil outlet tubes 84, in case such suction isgreater than the natural rise of the gases to the top of the tank 74.Evidently, there is more than a single measure set in place to precludegiant inflammable gas bubble to admix with liquid petroleum in it'scollection system. This is a simplest model that can be incorporated atthe oil well surface to separate gas under pressure (the target beingmitigating dangerous calamities, rather than pursuing 100% refiningmeans of oil gas separation) unlike a complicated set up, involved inthe model of the exclusive ‘oil production plants’ of crude oilseparation (oil refineries) by fractional distillation.

The OGS device is obviously intended to mitigate possible entrainment ofinflammable gas into the liquid petroleum collection system. Compared tothe enormous resistance exerted by the conventional BOP (with bothweight and pressure contributing to such pressure resistance), thedevice unit described as in the OGS seems too simplistic, but there isan inherent difference that is taken advantage of, to propose such amodel. The principle involved in the BOP is to ultimately resist thepressure of a giant gas bubble, which may not be always successful,because there is no ‘set limit’ to the pressure of such entrained gas,and at unexpected thresholds, the BOP is bound to fail. The OGS makes noeffort to resist such gas pressure, as at certain threshold, it isuncontrollable. Accordingly, it is prudent to let out such pressure,totally if possible, and in case it is only partial, at least theopposing pressure is optimized, for the surface BOP near the rig levelto be able to control. Obviously, it is not the intention of the plan ofthe OGS device to control a liquid oil gusher from the well.

Workable Alternate Plans—

For the BOP to control pressures involving most powerful of ruptures, inall high volume wells where such events can be reasonably expected, itis a worth trying option to divide the oil line into multiple outletconduits with in the inner most casing, instead of running single, andeach outlet conduit is structured to pass through it's own stacks ofBOP, so that each stack of BOP can tackle the divided power of thegusher, reduced to half, or third of it's strength. Additionally, it isalso a good practice to never allow a production casing to be afunctioning oil conduit in high volume wells, a brewing recipe fordanger.

The base piece of the drilling riser can have an oil outlet tube and anoil inlet tube to accommodate this OGS equipment in the well vicinity onthe sea floor, in situations where oil collecting tubular system travelsin the drilling conductor to the rig vicinity. Alternatively, it can bein the vicinity of the rig (if it is a mandate), but structurallyseparated by a safe distance, so that any possible ignition spark(inherent in the rig, as a unit, to where the inflammable gases shouldnever find their way) to set fire the highly inflammable gases can bestrictly precluded, which is a basic and most efficacious preventivemeasure, when all else can possibly fail.

7) Threaded Instant Joint Configurations

The invention also envisions that all future ‘Production Tubing’ or anytubing, (except the well casings), involving the rig, oil collectiontubing, and oil well construction be invariably built with deep inner orouter threading through out, to immediately repair the damage bypromptly attaching a ‘replacement tubing’ (with or with out nestingconfiguration of the articulating ends), in case ‘fire and well surfaceblow out’ happen, resulting in a ‘disconnect’ in the system, or to closethe system any where necessary, with complimentary capping. Suchstructural mandate is as important as all the incorporated safetydevices. The broken tubular structures articulate with new tubing withcomplimentary outer/inner threading by direct connections, or through‘connecting joints’ configured in many shapes—I, L, U, C, Y, J, T etc.in plain or in nested configuration, and having inner/outercomplimentary threading, to be used as one or multiple joints (one ormore ‘I’ joints are usually needed to incorporate other jointstructures, to restore a conduit line, or complex interconnections, orthey can be closed, where ever necessary, by complimentary capping.

CONCLUSION OF SPECIFICATIONS

Although the description of all the above embodiments contain manyspecificities, for descriptive purposes, these should not be construedas limiting the scope of the invention but as merely providingillustrations of some of the most preferred embodiments, yet allowingminor changes as fit for each uniquely differing situation andcircumstance, too numerous to exemplify.

1. An embodiment of invention, directed to innovative modelsencompassing emergency devices designed to be working in synchrony, andtheir plurality of methods directed to salvaging a crumbled oceanicpetroleum oil well, by means effectuating sealing an oil leak, andfurther reparative processes, restoring either or both of temporary andpermanent functioning of the well structure, incorporating— (1)Emergency pneumatic sealing devices, and their stabilizing instrumentsfor effectively sealing a leaking oceanic petroleum oil well, with awell head and inner casing disrupted, causing oil/gas spill into theoceanic grounds, said devices made of steel and vulcanized rubber(polysulfide elastomer) resisting petroleum analogs, and devised toeffectively seal: (a) an incomplete oil well devoid of production tubingand production packer, having disrupted innermost casing, with theproduction casing subject to be a dimension sealed, it's sealing deviceencompassing a device of ‘Emergency Pneumatic Sealer Ensemble’ (EPSE),either simpler (the simple sealing device, SSE), or involved in it'sstructural design (the EPSE Unit), (b) high production oil wells notdestined for production tubing, their disrupted production casing makingan oil conduit, subject to be a dimension sealed, it's sealing deviceencompassing a device of Emergency Pneumatic Sealer Ensemble (EPSE),either simpler (the Simple Sealing Design, SSE), or involved in it'sstructural design (the EPSE Unit), (c) completed oil well withfractured/severed production tubing, the lumen of the tubing subject tobe the diameter sealed, it's sealing device encompassing a device ofEmergency Plugging Oil Conduit (EPOC), (2) an emergency oil connectingand stabilizing unit (EOCS unit) of the EPSE device, (3) an emergencystabilizing unit incorporating a well head (ESUWH) devised in heavyweight steel, and stationing at the disrupted oceanic petroleum wellsurface, subject to stabilizing any pneumatic sealing device, andfurther encompassing a metal frame work for structuring a cementedplatform, (4) emergency reparative measures at the well headencompassing methods of restoring a disrupted oceanic petroleum wellsubject to cement structuring an emergency isolation platform (EIP), (5)emergency responsive measures directed to a marine rig subject to anignition fire following an entraining of gases, incorporating devicesand their methods leading in further prevention, (6) devices and theirmethods directed to a model of oil gas separator (OGS) mitigatingemergency failing of a blow out preventer (BOP), such devices andmethods subject to dispersing a giant gas bubble entering collectionsystem of the petroleum oil.
 2. An embodiment of invention directed toEmergency Pneumatic Sealer Ensemble of an involved design (EPSE Unit) ofclaim 1, made of vulcanized rubber, subject to sealing a fracturedproduction casing, as an inflatable air sealer, stationing at a level ofan intact well bore mapped by video/sonar imaging, such stationingcausing by easy, emergent, and robotic maneuvers, and the said EPSE Unithaving— (a) made of a spindled body of rubber coat, (b) having a length(vertical height) averaging five feet, and a diameter averaging eightinches, before subject to be inflating, (c) having a central oil conduitof metal (steel), comprising an average diameter of 5-10 cm., (d) havingan upper and a lower dome of reinforced rubber, housing metal spoolswith flanges, such flanges making a joint and a continuum of a metal oilconduit having a similar diameter, occupying the center of the rubberdevice, and emerging above and below, (e) wedging preferably an intactcasing interior of disrupted petroleum well, being sub-maximally ormaximally inflated, subject to optimal calibrating pressure, maintaininga safety margin from burst pressure, (f) housing an upper and a lowerset of inflatable air capsules of vulcanized rubber, the upper setattaching to the upper dome, and the lower set attaching to the lowerdome, and a horizontal central partition of rubber separating each setcomprising 6-8 air capsules, each air capsule measuring 2 feet inheight, and positioning in circular manner around the central oilconduit, said air capsule further encompassing:
 1. an inflating colorcoded air tubing of vulcanized rubber, having automated, mechanical, oneway check valve at it's joining of the air capsule, allowing air flow tothe capsule, the said air tubing coiling before joining the said aircapsule;
 2. a bundle of said color coded inflating air tubing entering ared colored rubber hose, coursing along the oil conduit, and emergingfrom the upper dome, to be further traveling to an air source;
 3. adeflating tubing of each capsule having no valve, and traveling in agreen hose to monitoring station, where their tubing are generallyclamped, except for deflating;
 4. maintaining the needing wedge pressureby on going pressure monitor system;
 5. a means of precipitous fallingin pressure of a punctured air sac, and a gradual fall of it's adjoiningsacs, causing such adjacent members subject to more air pumping, forfilling the lost contour of the pneumatic ensemble; (g) housing areserve set of air capsules encompassing similar structure, andattaching to the central partition:
 1. to be inflated when it's memberis punctured;
 2. expanding to the upper or lower dome;
 3. their airtubing system setting forth a conjoining system forking at the aircapsule and at the monitoring station;
 4. their forking at the airsource having a thinner configuration;
 5. having generally clampedlumens only unclamping for inflation; (h) the EPSE further having inneror outer threading to the inlet and the outlet oil conduit tubing, forarticulating with complementary threading, for either for continuing, orcapping it's conduit tubing.
 3. An embodiment of invention, directed toa device of Emergency Sealer Ensemble (EPSE) of claim 1, encompassing asimpler design, the Simple Sealing Ensemble (SSE), made of vulcanizedrubber, subject to sealing a production casing of a leaking oceanic oilwell, as an inflatable air sealer, at a destined level mapped byvideo/sonar imaging, the stationing causing by easy, emergent, androbotic maneuvers and the said SSE device— (a) having single aircapsule:
 1. attached to the lower dome;
 2. encompassing an automated,mechanical, one way check valve at it's joining with an ‘inflating’vulcanized air tubing;
 3. further having a ‘deflating’ air tubingcomprising vulcanized rubber, with no valve guarding, and generallyclamped at the air source, except for deflating, (b) having singlereserve air capsule encompassing a similar configuration, and attachingto the upper dome, subject to clamping at the air source, except wheninflating, taking the position of the lost capsule, (c) comprising asingle rubber hose housing all air tubing, inflating and deflating,defining any different color coding, and coursing along the central oilconduit, to be reaching the air source.
 4. An embodiment of inventioninvolving an Emergency Oil Conducting and Stabilizing Unit (EOCS unit),encompassing any of the EPSE devices of claim 1, comprising lengtheningsegments of metal (steel), subject to— (a) each lengthening segmentmeasuring 2-5 feet, or longer; (b) each having an internal diameter of5-10 cm., conforming to configuration of a production tubing, settingforth an oil conduit; (c) articulating with each other; (d) articulatingwith the upper oil outlet tube of the EPSE device; (e) articulating witha central piece of an Emergency Stabilizing Unit Incorporating a WellHead-like structure (ESUWH), on the well surface; (f) each set of twosegments articulating, with further provisions of having snapping metallocks, such train of articulating segments lengthening to the stationinglevel of the EPSE device.
 5. An embodiment of invention, encompassing adevice of ‘Emergency Plugging oil Conduit’(EPOC) of claim 1, directed tosealing a leaking ‘Production Tubing’, partially or completely fracturedat any level, in a disrupted leaking oceanic petroleum oil well, thesaid EPOC device comprising: (a) a metal tubing of steel, involving manyfeet in length, directed to sealing a substantial length of the lowercomponent of a production tubing, the disrupted/distorted uppercomponent having been naturally dismantled as a whole, or set to be sodismantled, (b) a metal tubing of steel, configured 1-2 centimetersnarrower in caliber than the standard production tubing of 5-10 cmdiameter, (c) a metal tubing of steel, having a covering of strongvulcanized rubber sheath, except over it's upper and lower ends, to beinflating to calibrated optimum pressure, with in the lumen of the lowercomponent of a production tubing having a dismantled upper segment,resulting an effective pneumatic sealing through out it's length, within the lower segment of the production tubing, (d) a metal tubing ofsteel, having it's upper end structured in a manner similar to aconduction tubing, facilitating articulation with a well head-likestructure, encompassing an ESUWH unit, (e) a metal tubing of steel,having it's pneumatic outer sheath of vulcanized rubber connecting to aninflating air source, and having optimum air pressure monitoring foreffective sealing, until the time of it's planned deflation.
 6. Anembodiment of invention directed to an Emergency Stabilizing Unit withWell Head-like Structures (ESUWH), subject to be stabilizing a pneumaticsealing ensemble set forth to be sealing the leaking oceanic Petroleumoil well bore of claim 1, said ESUWH device subject to be— (a)stabilizing an EPSE devise of any type, pneumatically sealing a leakingproduction casing, and further fitted with an EOCS unit, (b) stabilizingan Emergency Plugging Oil Conduit (EPOC), pneumatically sealingproduction tubing, (c) having a table like configuration with roundedtop, and outwardly spanning and widening four legs, drilled into, andsecured upon cementing to the sea floor, (d) having a central hole inthe top, housing a well head-like structures, encompassing an oilconduit, and a blow out preventer (BOP), (e) stationing at the disruptedwell head, and made of heavy weight steel, (f) having dimensions to beconforming to a metal frame of an incorporating cement platform, makinga permanent structuring of a well head.
 7. An embodiment of invention,encompassing the materials and methods for devising an EmergencyIsolation Platform (EIP), a reparative permanent structure at thedisrupted well head of an oceanic petroleum oil well, as in claim 1, setforth in cement and metal, and drilled and cemented into the sea bed,comprising following devices and methods: (a) installing a noveladdition of inverted funnel shaped base piece of the drilling riser,wide enough accommodating a ‘new cement structuring’ on a reliable solidground, beyond the measured maximum diameter of disruption (DOD), (b)making a ring shaped and elevated cement platform, by-passing themaximum diameter of disruption marking the originally placed well head,the said cement structure incorporating the ESUWH device as a stablemetal frame of scaffold, (c) further raising a cemented platform overthe ring shaped cement floor, and extending a roof to the center, overand bypassing the DOD, for incorporating a well head-like structures inthe central piece of the ESUWH device, (d) flushing the roof with thesea bed as a sloping circumferential cement platform under the funnelbase of the drilling riser, the whole of the said cement platformincorporating cement slurry through robotic arms, (e) further burrowingthe periphery of the cement platform under the edge of the funnel baseof the riser, (f) cementing a new ‘reparative well casing’ hung from thewell head for positioning inside the smallest disrupted well casing,such reparative casing encompassing a depth of 1-2 reparative strings, avideo or sonar imaging defining such depth of disruption, the cementinginvolving a conventional circulating of cement slurry into the casingshoe, and the annulus, (g) the cement roof devised to be letting out anyoil/gas column making it's way from the disrupted sea bed, by one of thefollowing measures of having:
 1. tubules studded in the cement roof,said tubules having an inverted J shape, and mechanical one way valve,letting the oil/gas out, the down turned J tube on the out sidemitigating hydrostatic pressure on the valve, and if further ocean watersampling showing dangerous emissions, the tubules closed bycapping/cementing, such plan conforming to well heads in open ocean,having no drilling riser;
 2. having a wider tube in the cement roof,fitted with one way valves to let the oil/gas out, the tube conformingto inverted L shape, it's horizontal limb joining the main oil pipe,such plan conforming to well heads in open ocean, or the oil wellshaving intact drilling riser, enclosing a well top.
 8. An embodimentencompassing a Detachable Island Rig (DIR), stationing on a stableconcrete base off shore, to be instantly detaching upon a fire, andhaving means plus function of: (a) the DIR to instantly unlock/lock by acar door like locking device to be disengaging/engaging with theconduction platform and a station of immovable structures, the DIRseparating from an intervening stretch of corridor, being fire proof,and having tubes and electric wires traversing either wall, (b) thedetachable rig (DIR) having: additional conduction platform, costlyequipment, reserves, living and working quarters, and at the farther enda steering station having engine with powerful motor to speed steer inan automated straight course following a remote signal by the crew, andthe unlocking of the DIR from the concrete base, (c) the stationary rigand the detachable rig having their own fire stations and crew of firefighters, (d) the detachable rig has life boats with wheels, stationingaround the deck for lowering into the sea by projectile ramps, in theevent the DIR also catching fire that can not be contained, (e) The DIRwhile steering away shall be releasing life boats for rescuing the firefighters staying back, and jumping into water in life threateningsituations, said life boats having special features of
 1. a ladder onone side,
 2. the whole boat painted white, and having black and whitestripes on the side of the ladder, and further having fire resistantsurface,
 3. the hemi section of the boat on the opposite side of theladder having thicker heavy weight wood preventing toppling of the boat,with weight on the other side,
 4. having secured oars inside, andinstant disengaging snaps to the anchoring metal chains, to be steeringaway from the rig, (f) the DIR incorporating car door like lockingdevices on all sides except the side of the steering engine, andunlocking by remote control, having common button to each side, (g) allthe tubing passing through a stretch of fire proof corridor, at thejunction with the DIR are conforming to short segment of rubber tubinghaving C or U shapes, to be cut after clamping causing an instant DIRdetachment, (h) the DIR can be constructed on a vertically adjustableplatform, maintaining optimum submersion of it's base structure inwater, and further having wheels like those of a shopping cartprojecting at the base when needed, for positioning on it's baseplatform, (i) the DIR, for stationing back onto the concrete base, ispulled down by a system of double pulleys on strategic positions overthe concrete base having pull-over ropes linking to series of rings onthe sides of the DIR.
 9. An embodiment of invention encompassing adevice and it's method of operation, as an effective ‘Oil Gas Separator’(OGS), directed to preventing giant bubbles of inflammable gas enteringpetroleum oil collecting system from a source of oceanic oil well, thedevice and it's plan of operation, comprising— (a) diverting the crudeoil/gas from the collection tube, located past the well head, into a setof 3-4 oil gas separator tanks, each having an independent tube arisingfrom the main tube, and rising only few inches (8-10 inches) into thetank, and the oil in the tank set to maintaining a level far lower than8 inches, (b) each tank of the set having a perforations to it's bottom,letting the oil flowing away through it's holes to be collecting downinto yet another compartment, having intact walls and an out let tube,such holes of the tank subject to dispersing the gas into bubbles ofsmaller dimension, (c) each tank further having two gas out let pipes inthe top, for letting out the rising gas by means of a different gascollecting system, into gas receptacles, in a safe distance away fromthe rig, (d) the tubes leading from the bottom of the tank are to beentering the main oil pipe at widely varying heights, further separatinga large gas column if any, for breaking the gas entrainment, (e) eachtank further having a churner in the top, resembling in structure akitchen mixer, and moving down the bottom every few seconds, breakinglarge sized semisolid crude, preventing a possible block, (f) each entrytube to a tank further having on/off clamps controlling volume flow ofthe tank, and further for disconnecting a tank, only high volume wellssubject to operating all tanks, (g) the base piece of a drilling risercan be structured to be having an oil out let and an inlet tubefacilitating an OGS unit near an oceanic oil well, subject to separatingoil-gas at the source, preventing gas entraining and rig endangering byan ignition spark.
 10. An embodiment of invention providing novel modelsof tubing, and their methods of instant system joining or closing,directed to tubular systems encompassing the preferred inventions ofclaim 1, the said tubing structured to be having a threadingconfiguration inside or out, traversing a whole lumen of any suitabletubing, facilitating instant joining or closing of a broken or intactsystem anywhere, by direct joining with a similar tube and complimentarythreading, or by means of ‘instant joints structures’ as I, T, J, L, C,U etc. or closure caps with complimentary threading, having straight ornested configuration, such joining needing at least one or two ‘I’joints, restoring a straight or a complex interconnection.